HomeMy WebLinkAbout17-3645 ord1
ORDINANCE NO. 17-3645
AN ORDINANCE OF THE CITY COUNCIL OF THE CITY OF PLAINVIEW,
TEXAS APPROVING A SETTLEMENT AGREEMENT BETWEEN THE
ALLIANCE OF XCEL MUNICIPALITIES ("AXM") AND SOUTHWESTERN
PUBLIC SERVICE COMPANY ("SPS" OR "COMPANY") REGARDING
THE COMPANY'S STATEMENT OF INTENT TO CHANGE ELECTRIC
RATES IN ALL CITIES EXERCISING ORIGINAL JURISDICTION;
DECLARING EXISTING RATES TO BE UNREASONABLE; ADOPTING
TARIFFS THAT REFLECT RATE ADJUSTMENTS CONSISTENT WITH
THE SETTLEMENT AGREEMENT AND FINDING THE RATES TO BE
SET BY THE ATTACHED TARIFFS TO BE JUST AND REASONABLE;
FINDING THE CITY'S RATE CASE EXPENSES REASONABLE;
DIRECTING SPS TO REIMBURSE THE CITY ITS REASONABLE RATE
CASE EXPENSES; DETERMINING THAT THIS ORDINANCE WAS
PASSED IN ACCORDANCE WITH THE REQUIREMENTS OF THE
TEXAS OPEN MEETING ACT; DECLARING AN EFFECTIVE DATE;
REPEALING ANY PRIOR RESOLUTIONS OR ORDINANCES
INCONSISTENT WITH THIS ORDINANCE; AND REQUIRING DELIVERY
OF THIS ORDINANCE TO THE COMPANY AND LEGAL COUNSEL.
WHEREAS, the City of Plainview, Texas ("City") has exclusive original jurisdiction
as a regulatory authority over Southwestern Public Service Company ("SPS" or
"Company") rates, operations, and services within the City; and
WHEREAS, the City is also an electric utility customer of SPS, and has an interest
in SPS's rates and charges; and
WHEREAS, SPS filed a Statement of Intent with the City on or about February 16,
2016 to increase its annual revenue requirement by approximately $71.9 million on a
Texas retail jurisdictional basis, which represents an increase in base revenues of
approximately 14.41%, and which included an increase in residential base rates of
approximately 11.23%; and
WHEREAS, the City took action to suspend the effective date and to coordinate a
response to SPS's filing with other similarly situated municipalities (such participating
cities are referred to herein as the Alliance of Xcel Municipalities ("AXM")); and
WHEREAS, the City took action on or before March 22, 2016 to suspend the
effective date; and
WHEREAS, one of AXM's goals is to minimize rate -case expenses to the extent
reasonable, that otherwise would result from lengthy, contested rate -case proceedings
before the Public Utility Commission of Texas ("PUCT") and through the appellate
process in the courts for the pending rate case; and
PAGE 1 of 5
2
WHEREAS, AXM authorized its attorneys and experts to formulate and review
reasonable settlement positions to resolve SPS' pending request to increase rates; and
WHEREAS, AXM's attorneys met numerous times with the Company to negotiate
a Settlement Agreement resolving the issues raised by the Company's Statement of
Intent filing; and
WHEREAS, after extensive review and analysis, AXM's attorneys and experts
found that SPS's initially proposed increase in revenue and its initially proposed rates are
unreasonable; and
WHEREAS, AXM's attorneys and experts have evaluated what a likely outcome
from a fully -litigated proceeding would be and are of the opinion that the increase of
approximately $35 million noted in the negotiated Settlement Agreement compares
favorably with a likely outcome from a fully -litigated proceeding; and
WHEREAS, after extensive review and analysis, AXM's attorneys and experts
found that the significantly lower increase of approximately $35 million instead of the
$71.9 million increase initially proposed by SPS is reasonable; and
WHEREAS, under applicable law, the settlement rates are effective retroactively
for consumption on or after July 20, 2016; and
WHEREAS, AXM's attorneys and experts and AXM's Steering Committee, based
on the advice of its attorneys and experts, recommend that AXM's members approve the
negotiated Settlement Agreement and attached tariffs; and
WHEREAS, under the Public Utility Regulatory Act, the City has a right to
reimbursement of its reasonable rate -case expenses and SPS has an obligation to
reimburse the City's reasonable rate -case expenses; and
WHEREAS, the attached tariffs implementing new rates are consistent with the
Settlement Agreement and are just, reasonable, and in the public interest; and
WHEREAS, the Settlement Agreement as a whole is in the public interest.
NOW THEREFORE, THE CITY COUNCIL OF THE CITY OF PLAINVIEW, TEXAS
HEREBY ORDAINS:
Section 1. The findings set out in the preamble are in all things approved and
incorporated herein as if fully set forth.
Section 2. The City Council finds that the Settlement Agreement, which is
attached hereto as EXHIBIT A and incorporated herein, is in the public interest and is
hereby endorsed in all respects.
PAGE 2 of 5
3
Section 3. SPS's existing rates are found unreasonable upon the
implementation of the rates set forth in the Settlement Agreement.
Section 4. The revenue and resulting rates set forth in the Settlement
Agreement and schedule of rates and tariffs for electric service provided by SPS, which
are attached to the Settlement Agreement as "Attachment B," are just and reasonable,
and are hereby adopted for consumption on and after July 20, 2016.
Section 5. The baseline amounts set forth in the Settlement Agreement and
attached to the Settlement Agreement as "Attachment D" are approved subject to the
conditions stated in the Settlement Agreement.
Section 6. The rates under the Settlement Agreement shall be effective for
consumption on and after July 20, 2016.
Section 7. SPS shall seek the City's approval of any surcharge that may be
necessary to recover revenue foregone by SPS under rates pursuant to the Settlement
Agreement and its current rates from July 20, 2016 to the date when the rates under the
Settlement Agreement are approved.
Section 8. To the extent any resolution or ordinance previously adopted by the
Council is inconsistent with this Ordinance, it is hereby repealed.
Section 9. The meeting at which this Ordinance was approved was in all things
conducted in strict compliance with the Texas Open Meetings Act, Texas Government
Code, Chapter 551.
Section 10. If any one or more sections or clauses of this Ordinance is adjudged
to be unconstitutional or invalid, such judgment shall not affect, impair or invalidate the
remaining provision of this Ordinance and the remaining provisions of the Ordinance shall
be interpreted as if the offending section or clause never existed.
Section 11. This Ordinance shall become effective from and after its passage.
Section 12. The City Secretary or other appropriate city official shall notify SPS
of this Ordinance by sending a copy of the Ordinance to Evan Evans, Regional Vice
President, Rates and Regulatory Affairs, Southwestern Public Service Company, P.O.
Box 1261, Amarillo, Texas 79105-1261 and AXM shall be notified by sending a copy of
this Ordinance to Mr. Alfred R. Herrera, Herrera & Boyle, PLLC, 816 Congress Ave., Suite
1250, Austin, Texas 78701.
PASSED AND APPROVED on first reading this 22nd day of December, 2016.
PASSED AND APPROVED on second reading this 10th day of January, 2017.
PAGE 3 of 5
ATTEST:
Belinda Hinojosa, City Secreta
Wendell Dunlap, Mayor
PAGE 4 of 5
SPS RATE ORDINANCE
Exhibit A
SPS 2016 Statement of Intent
Stipulation and Settlement Agreement
PAGE 5 of 5
SOAH DOCKET NO. 473-16-2520
PUC DOCKET NO. 45524
APPLICATION OF SOUTHWESTERN § BEFORE THE STATE OFFICE
PUBLIC SERVICE COMPANY FOR § OF
AUTHORITY TO CHANGE RATES § ADMINISTRATIVE HEARINGS
UNOPPOSED STIPULATION
(Filename: 45524 Unopposed Stipulation.docx; Total Pages: 134)
Table of Contents
UNOPPOSED STIPULATION 3
I. Agreement as to Base Rate Increase 4
II. Interim Rates 5
III. Rate Case Expenses 5
IV. Resolution of Accounting Issues 5
V. Baselines 6
VI. Future TCRF Application 7
VII. Renewable Energy Credits 8
VIII. Allowance for Funds Used During Construction ("AFUDC") 8
IX. Schedule S Waiver 8
X. Cost Allocation and Rate Design 8
XI. Transition Plan to Eliminate the Residential Space Heating Rate 8
XII. Study Regarding LED Street Lighting 10
XIII. Future Treatment of LGST Class 10
XIV Classes for Future SPS EECRF Filings 10
XV. Proposed Order 11
XVI. Obligation to Support this Stipulation 11
XVII. Effect of Stipulation in this Proceeding 11
XVIII. Effect of Stipulation in Other Regulatory Proceedings 12
XIX Multiple Counterparts 13
SOAH Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-1-
000001
CERTIFICATE OF SERVICE 27
ATTACHMENTS:
Attachment A — Proof of Revenue 28
Attachment B — Rate Tariffs 38
Attachment C — Power Factor Revenue Regulatory Asset Agreement 113
Attachment C-1— Baseline Level of Power Factor Adjustment Charge Revenue 117
Attachment D — TCRF, DCRF, PCRF, and Pension/OPEB Baselines 118
Attachment E — Proposed Final Order 123
SOAR' Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-2-
000002
7
SOAH DOCKET NO. 473-16-2520
PUC DOCKET NO. 45524
APPLICATION OF SOUTHWESTERN § BEFORE THE STATE OFFICE
PUBLIC SERVICE COMPANY FOR § OF
AUTHORITY TO CHANGE RATES § ADMINISTRATIVE HEARINGS
UNOPPOSED STIPULATION
The Signatories to this Unopposed Stipulation ("Stipulation"), which is dated as of
December _, 2016, are the following:
• Staff ("Staff') of the Public Utility Commission of Texas ("Commission");
• Southwestern Public Service Company ("SPS");
• Texas Industrial Energy Consumers;
• Alliance of Xcel Municipalities ("AXM");
• Office of Public Utility Counsel ("OPUC");
• United States Department of Energy;
• Amarillo College;
• International Brotherhood of Electrical Workers Local Union 602;
• Texas Cotton Ginners' Association;
• Pioneer Natural Resources USA, Inc.;
• Amarillo Recycling Co., Inc.;
• Wal-Mart Stores Texas, LLC, and Sam's East, Inc.; and
• Canadian River Municipal Water Authority.
Golden Spread Electric Cooperative, Inc. does not join this Stipulation, but does not
oppose it.
The parties who are joining this Stipulation shall be referred to individually either as a
Signatory or by the acronym assigned above, and collectively as the Signatories. The parties
who do not join this Stipulation but do not oppose it shall be referred to collectively as
Unopposed Parties. The Signatories submit this Stipulation to the Commission as representing a
just and reasonable disposition of the issues related to this docket consistent with the public
SOAH Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-3-
000003
interest. The Signatories request approval of this Stipulation and entry of findings of fact and
conclusions of law consistent with that approval.
On February 16, 2016, in accordance with Chapter 36 of the Public Utility Regulatory
Act, Tex. Util. Code Ann. §§ 11.001-66.016 (West 2016) ("PURA"), SPS filed its application
with the Commission seeking authority to revise its base rates based upon a test year of October
1, 2014 through September 30, 2015 ("Test Year"), updated to include information that reflected
SPS's most current actual information through December 31, 2015, as authorized by PURA
§ 36.112. SPS's application, as later modified by rebuttal testimony, requested, among other
things, that the Commission authorize a $61,498,468 increase in SPS's Texas retail jurisdictional
base rate revenues. SPS requested that the final rates set in this proceeding relate back to July
20, 2016 in accordance with PURA § 36.211. The statutory deadline was originally October 3,
2016, but SPS agreed to extend the statutory deadline from that date until January 31, 2017.
By this Stipulation, the Signatories resolve all of the remaining issues among them
related to SPS's application, and agree as follows:
I. Agreement as to Base Rate Increase
a. The Signatories agree that SPS's Texas retail rates will be set to recover a revenue
requirement of $545 million, and that SPS's present revenues total $509,750,239,
which results in a base rate revenue increase of $35,249,761 for service rendered
on and after July 20, 2016. The increase by class and revenue proof is reflected in
Attachment A to this Stipulation. The rate tariffs are provided in Attachment B to
this Stipulation.
b. The Signatories agree that $12,599,674 reflected in Attachment A to the
Stipulation is attributable to power factor adjustment charges. As described in
Attachment C to this Stipulation, if SPS's actual power factor adjustment
revenues are less than $12,599,674 on an annual basis during the applicable
period, SPS will record the difference in a regulatory asset and will be authorized
to seek recovery of that amount under the terms set forth in Attachments C and C-
1.
SOAH Docket No. 473-16-2520
PUC Docket No. 45524
-4-
Unopposed Stipulation
000004
9
10
II. Interim Rates
a. The Signatories recognize that the $35,249,761 rate increase set forth in Section i
of this Stipulation relates back to service rendered on and after July 20, 2016.
Therefore, the Signatories agree that SPS may file a motion requesting that the
Administrative Law Judges ("ALJs") approve interim rates to begin on the date of
the ALJs' order approving those interim rates for usage on and after that date.
The tariffs authorizing the interim rates will be identical to the tariffs attached as
Attachment B to this Stipulation. The motion for interim rates will further specify
that the interim rates are subject to adjustment if the interim rates differ from the
final rates the Commission approves in this proceeding.
b. If the Commission's final order in this docket approves the $35,249,761 base rate
increase set forth in Section I of this Stipulation, no true -up of interim rates that
became effective under Section II.a. of this Stipulation shall be necessary because
the interim rates will be identical to the final rates approved by the Commission.
c. If the Commission does not approve this Stipulation, SPS shall institute a refund
or surcharge after the date on which the Commission's order in this docket
becomes final to refund the interim rates implemented under Section TI.a. of this
Stipulation.
d. For service rendered on and after July 20, 2016 through the day before the date
SPS begins implementing the interim rates, SPS may implement surcharges and
refunds, as applicable, to recover the revenue it would have received during that
period if the tariffs provided in Exhibit B had been in effect during that period.
III. Rate Case Expenses
The Signatories agree that the agreed-upon base rate increase does not include rate case
expenses, which will be addressed in Commission Docket No. 46328.
IV. Resolution of Accounting Issues
a. The pension and Other Post -Employment Benefit ("OPEB") expense tracker
balances will be measured as of May 31, 2016, and the amortization of those
SOAHDocket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-5-
000005
balances will begin July 1, 2016. Any remaining unamortized amounts can be
included in a subsequent base rate case filing and are deemed reasonable and
necessary.
b. There will be no change in SPS's existing Commission -approved depreciation
rates. A new amortization period of 15 years is established for large base system
software assets.
c. The capital additions that SPS closed to plant in service during the period of July
1, 2014 through December 31, 2015 that are included in SPS's Test Year and
Update Filing rate base are reasonable and necessary.
V. Baselines
a. The Signatories agree to the baselines set forth in Attachment D to this Stipulation
for:
1. the Transmission Cost Recovery Factor ("TCRF"):
2. the Distribution Cost Recovery Factor ("DCRF")
3. the Purchased Power Capacity Cost Recovery Factor ("PCRF"); and
4. the pension and OPEB expense tracker.
b. The weighted average cost of capital for the TCRF, DCRF, and PCRF baselines is
7.7%.
c. The inclusion of separate baseline numbers for the Residential Space Heating
("RSH") rider customers is not an agreement by the parties that any TCRF,
DCRF, or PCRF rate should or should not be set separately for these customers,
or that the separate baseline numbers for the RSH and other residential customers
are or are not appropriate to use in calculating a TCRF, DCRF, or PCRF revenue
requirement. Further, all Signatories reserve their rights in TCRF, DCRF, and
PCRF proceedings that use the baselines set forth in Attachment D regarding
whether the TCRF, DCRF, or PCRF rates should reflect separate rates for RSH
customers.
SOAK Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-6-
000006
11
12
d. In addition, all Signatories agree that any list or any level of detail of the various
ratemaking components (costs, rate base items, jurisdictional allocators, etc.) in
the TCRF, DCRF, and PCRF baselines set forth in Attachment D are the product
of compromise and settlement, and are non-binding and not to be treated as
precedent in any other proceeding of any kind (base rate, rulemaking, TCRF,
DCRF, PCRF, or otherwise) involving any utility (not just SPS proceedings).
Notwithstanding the agreement in this section, and except with regard to which of
the baseline columns related to residential customers to use,1 baseline values set
forth in Attachment D will be used in TCRF, DCRF, or PCRF cases SPS files
before its next base rate case. The fact that parties have agreed to the use of the
baselines as specified in this section does not reflect an agreement on any
methodology that may or may not have been used to derive those baselines.
VI. Future TCRF Application
For the first TCRF application SPS files after the date this Stipulation is filed with the
Commission:
a. if SPS files a TCRF application that uses test year data only (no post-test year
capital additions, only the level of approved transmission charges incurred during
the test year, with adjustments only to remove non-recurring and out of period
items, and makes a load growth adjustment (see item VI.c.)), the Signatories and
Unopposed Parties will not oppose setting a procedural schedule that includes the
following terms: (i) parties will agree to set a deadline to request a hearing within
45 days of the filing of the application, and (ii) if no hearing is requested or if the
parties reach an agreement regarding all issues, the parties will make reasonable
efforts for a final order to be entered on or before the 100th day after the filing of
the application;
b. SPS agrees to a cap of $19 million (Texas retail) on an annualized basis for the
total amount of the increase that will be implemented;
SPS further agrees to use all columns related to residential customers.
SOAR Docket No. 473-16-2520
PUC Docket No. 45524
-7-
Unopposed Stipulation
000007
c. SPS will make a load growth adjustment to reflect actual billing determinants for
the TCRF test year; and
d. SPS will not file a TCRF application before the order entered in Docket No.
45524 becomes a final order under Tex. Govt. Code § 2001.144.
VII. Renewable Energy Credits
a. Bundled Texas -generated RECs will be priced at $0.39 starting on August 1,
2016; and
b. The Texas Commission will establish the value for Texas -generated bundled
RECs and the New Mexico Public Regulation Commission will establish the
value for New Mexico -generated bundled RECs.
VIII. Allowance for Funds Used During Construction ("AFUDC")
The Signatories agree that the return on equity for AFUDC purposes is 9.6%.
IX. Schedule S Waiver
For SPS's next base rate case, the Signatories agree not to oppose a request by SPS to
waive the requirement to file Schedule S of the current rate filing package, provided that the test
year (or update period) for the next base -rate case ends on the last day of a fiscal quarter.
X. Cost Allocation and Rate Design
a. The base rate revenue increases specified in Section I of this Stipulation will be
allocated and implemented through the rate design reflected in Attachment A.
b. The SPS rate tariffs as reflected in Attachment B are reasonable and should be
approved.
• Transition Plan to Eliminate the Residential Space Heating Rate
a. SPS, Staff, and OPUC agree to work cooperatively to develop a Residential
Service ("RS") rate design that SPS will propose in its next base rate case that
eliminates the RSH Rider. The new rate design for the Residential class will be
designed to moderate the effect on RSH customers of eliminating the RSH option,
SDAH Docket No. 473-16-2520
PUC Docket No. 45524
-8-
Unopposed Stipulation
000008
13
14
and may include options such as rates that are based on consumption bands. The
new rate design is intended to be revised or eliminated in future rate proceedings
as the need to moderate the effect of the elimination of the RSH Rider on RSH
customers diminishes. SPS agrees to make available upon request cost and billing
determinant information necessary to calculate RS rates based on initial
consumption band alternatives of 400 kilowatt-hours ("kWh"), 500 kWh, 600
kWh, 700 kWh, 800 kWh, 900 kWh, 1,000 kWh, 1,100 kWh, and 1,200 kWh.
b. If, in addition to the rate design addressed above, further mitigation of rate
impacts for RSH customers is necessary, SPS may propose a temporary rider
designed to provide a credit per kWh to all Residential customers for above-
average residential consumption during the winter months as defined in the
current RS rate tariff (billing months of October through May), to be phased out
over a period of time. The cost of the credit will be recovered through an increase
to the RS energy charge throughout the year, with the increase to be phased out
concurrent with the phase-out of the credit and the phase-out of the RSH rider, in
a manner designed to be revenue -neutral for SPS. The temporary rider will end at
the conclusion of the summer months as defined in the current RS rate tariff
(billing months of June through September) in the third year after the effective
date of the new rates set in SPS next base rate case, unless SPS, Staff, and OPUC
jointly recommend a different ending date and the Commission approves that
date. Rate changes under the temporary rider and the elimination of the rider are
not to occur during the winter months (as defined in the current RS rate tariff).
The target end date for the temporary rider is the end of the summer period
concluding September 30, 2020.
c. SPS, Staff, and OPUC agree to work cooperatively before SPS files its next base
rate case to: (1) develop a plan to inform RSH customers that the RSH option is
ending and to communicate to RSH customers the value of the Residential Time
of Use Rider; and (2) develop a plan to market the Residential Time of Use Rider
in general. SPS agrees to implement the plans prior to the conclusion of its next
base rate case.
SOAP! Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-9-
000009
d. Beginning with SPS's next base rate case, any cap on the number of customers
joining the residential time -of -use ("TOU") rate plans will not include a limit on
RSH customers seeking to participate in the TOU rate plans.
XII. Study Regarding LED Street Lighting
SPS agrees to conduct a study of cost savings associated with the installation of LED
lighting by municipalities and to present the results of that study in its next base rate case. SPS
will confer with AXM as it designs the study, and AXM and SPS agree to work cooperatively
regarding the study design. By entering into this Stipulation, no Signatory waives any claim it
may have regarding SPS's Tariff Sheet No. IV -91, Municipal and State Street Lighting Service,
or any other tariff for area lighting or sign lighting.
XIII. Future Treatment of LGST Class
SPS will treat LGST as a single class in its next rate case filing, including for cost
allocation and revenue distribution purposes.2 SPS will propose a single set of rates for the
LGST class, except that SPS will propose cost -based credit rates for energy and demand charges
applicable to higher voltage customers within the LGST class to reflect the lower line losses and
other identifiable cost differences associated with serving those higher voltage customers.
XIV. Classes for SPS EECRF Filings
For all SPS energy efficiency cost recovery factor ("EECRF") cases filed before the final
order in SPS's next base rate case becomes final, as defined under Tex. Govt. Code § 2001.144,
the classes approved in Docket No. 459163 will: (a) continue to be the classes for purposes of
SPS's EECRF cases; and (b) be considered the rate classes in SPS's "most recent base -rate
proceeding" under 16 Tex. Admin. Code § 25.181(c)(49). Those classes are:
Residential Service;
2 This provision is the result of an agreement between SPS and Commission Staff. The other parties to this
Stipulation do not oppose this provision.
3 Application of Southwestern Public Service Company to Adjust Its Energy Efficiency Cost Recovery
Factor, Docket No. 45916, Order at Finding of Fact No. 23 (Sept. 23, 2016).
SDAHDocket No. 473-16-2520
PUC Docket No. 45524
-10-
Unopposed Stipulation
000010
15
16
Small General Service;
Secondary General Service;
Primary General Service;
Small Municipal and School Service;
Large Municipal Service; and
Large School Service.
XV. Proposed Order
The Signatories agree to request entry of the proposed order shown on Attachment E to
this Stipulation.
XVI. Obligation to Support this Stipulation
The Signatories agree that they will support this Stipulation before the Commission.
XVII. Effect of Stipulation in this Proceeding
There are no third -party beneficiaries of this Stipulation. The Signatories agree that this
Stipulation resolves issues only with respect to the Texas retail jurisdiction and shall not be
binding on or have any effect on proceedings in other jurisdictions. Signatories are not agreeing
to any methodology or theory that may support or underlie any of the dollar amounts, rates in
tariffs, depreciation rates, dollar balances, or other monetary or numerical values set out in, or
attached to, this Stipulation.
This Stipulation has been drafted by all the Signatories and is the result of negotiation,
compromise, settlement, and accommodation. The Signatories agree that this settlement is in the
public interest. The Signatories agree that the terms and conditions in this Stipulation are
intended to work in concert with each other as an integrated whole for the purposes of an
outcome in this docket that is in the public interest and that will result in just and reasonable
rates. Thus, the various provisions of this Stipulation are not severable. None of the provisions
of this Stipulation shall become fully operative unless the Commission shall have entered a final
order approving this Stipulation. If the Commission issues a final order inconsistent with the
terms of this Stipulation, each Signatory has the right to withdraw from this Stipulation, to
SOAR Docket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-11-
000011
submit testimony, and to obtain a hearing and advocate any position it deems appropriate with
respect to any issue in this Stipulation.
XVIII. Effect of Stipulation in Other Regulatory Proceedings
This Stipulation is binding on each of the Signatories only for the purpose of settling the
issues as set forth herein in this jurisdiction only and for no other purposes. The matters resolved
herein are resolved on the basis of a compromise and settlement. Except to the extent that this
Stipulation expressly governs a Signatory's rights and obligations for future periods, this
Stipulation shall not be binding or precedential on a Signatory outside of this proceeding or a
proceeding to enforce the terms of this Stipulation. The Signatories recognize and agree that
Sections I.b., IV.a., VI, VII, IX, XI, XII, XIII, and XIV of this Stipulation all include forward-
looking provisions and corresponding obligations. Each Signatory acknowledges that a
Signatory's support of the matters contained in this Stipulation may differ from the position
taken or testimony presented by it in other dockets or other jurisdictions. To the extent that there
is a difference, a Signatory does not waive its position in any of those other dockets or
jurisdictions. Because this is a stipulated resolution, no Signatory is under any obligation to take
the same positions as set out in this Stipulation in other dockets or jurisdictions, regardless of
whether other dockets present the same or a different set of circumstances, except as otherwise
may be explicitly provided by this Stipulation. Agreement by the Signatories to any provision in
this Stipulation will not be used against any Signatory in any future proceeding with respect to
different positions that may be taken by that Signatory.
The provisions of this Stipulation are intended to relate to only the specific matters
referred to herein. By agreeing to this Stipulation, no Signatory waives any claim it may
otherwise have with respect to issues not expressly provided for herein. The Signatories further
understand and agree that this Stipulation represents a negotiated settlement of all issues in this
proceeding.
This Stipulation resolves the stated issues in the Texas retail jurisdiction only, and this
Stipulation does not resolve any claims, issues or proceedings pending in or pertaining to other
jurisdictions.
SOAHDocket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-12-
000012
17
18
XIX. Multiple Counterparts
Each copy of this Stipulation may not bear the signatures of all the Signatories but will be
deemed fully executed if all copies together bear the signatures of all Signatories.
Fully and duly authorized representatives of the Signatories have signed this Stipulation
as of the date first set forth above.
SOAH Docket No. 473-16-2520
PUC Docket No. 45524
-13-
Unopposed Stipulation
000013
STAFF OF THE PUBLIC UTILITY
COMMISSION OF TEXAS
By:
Doug Brown
Attorney of Record
ALLIANCE OF XCE UI\ITCIPAL1TIES
By:
Alfred Herrera
Jason Wakefield
Brennan Foley
Attorneys of Record
TEXAS INDUSTRIAL ENERGY
CONSUMERS
By:
Rex D. VanMiddlesworth
Benjamin Hallmark
Attorneys of Record
PIONEER NATURAL RESOURCES USA,
INC.
By:
James Z. Brazell
Attorney of Record
SOUTHWESTERN PUBLIC SERVICE
COMPANY
By:
Stephen Fogel
Ron H. Moss
Attorneys of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Sara J. Ferris
Attorney of Record
UNITED STATES DEPARTMENT OF
ENERGY
By:
Steven A. Porter
Attorney of Record
AMARILLO COLLEGE
13y:
Marlc D. White
Attorney of Record
TEXAS COTTON GINNERS ASSOCIATION INTERNATIONAL BROTHERHOOD OF
ELECTRICAL WORKERS LOCAL UNION
602
I3y:
Zach Brady
Attorney of Record
By:
Michael A. Murphy
Attorney of Record
SOAR Docket No. 473-16-2520 Unopposed Stipulator
PUC' Docket iVo. 45524
-14-
000014
19
20
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000015
000015
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000016
000016
21
22
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000017
000017
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000018
000018
23
24
THIS PAGE WAS INTENTIONALLY LEFT BLAND
000019
000019
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000020
000020
25
26
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000021
000021
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000022
000022
27
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000023
000023
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000024
000024
29
30
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000025
000025
THIS PAGE WAS INTENTIONALLY LEFT BLANK
000026
000026
31
32
CERTIFICATE OF SERVICE
I certify that on December _, 2016, a true and correct copy of the foregoing instrument
was served on all parties of record by electronic service, hand delivery, Federal Express, regular
first class mail, certified mail, or facsimile transmission.
SOANDocket No. 473-16-2520 Unopposed Stipulation
PUC Docket No. 45524
-27-
000027
Southwestern Public Service Company
Revenue at Settlement Rates
Line
No.
Description
Residential
1 RTX
2
3
4
5 RTXTOU
6
7
8
9 RSHTX
10
11
12
Service Availability Charge
Energy Charge - Summer
Energy Charge - Winter
Total
Service Availability Charge
Energy Charge - All Hours
Energy Charge - On -Peek Adder
Total
Service Availability Charge
Energy Charge - Summer
Energy Cbarge - Winter
Total
13 Total Residential Service
Small General Service
14 SGSTX Service Availability Charge
15 Energy Charge - Summer
16 Energy Charge - Wioter
17 Total
18 SGSTXTOU Service Availability Charge
19 Energy Charge - All Hours
20 Energy Charge - On -Peak Adder
21 Total
22 Total Small General Service
Billing Units
Base Rate Revenue
at Settlement Base Rates
Rate Revenue $
1,864,776 Bills
699,196,600 kWh
966,264,576 kWh
1,665,461,176 kWh
0
0
0
0
546,660 Bills
251,878,774 kWh
501,157,675 kWh
753,036,449 kWh
$ 10.00 / Month
$ 0.078572 / kWh
$ 0.068353 / kWh
Test Year at
Proposed
Rates
FUEL
Test Year at
Proposed
Rates
EECRF
r
Attachment A
Page 1 of 10
Docket No. 45524
Test Year at
Proposed
Rates
TOTAL REV
$ 18,647,760
54,937,275 $ 17,735,821
66,047,083 5 24,797,248
$ 139,632,118 5 42,533,069 S 1,112,528 $ 183,277,715
$ 10.50 / Month $
$ 0.058183 / kWh
$ 0.124929 /kWh
5 10.00 / Month
$ 0.078572 /kWh
$ 0.048582 /kWh
$
$ 5,466,600
19,790,619
24,347,242
$ 49,604,461
- $
- $
- $
$ 6,389,157
$ 12,861,209
$ 19,250,366 $ 503,028 S 69,357,855
418 497 625 kWh
S
189 236 579 S
6
783 435
$ 1 615 556 S 252 635 70
383,688 Bills
109,307,505 kWh
167,315,006 kWh
276,622,511 kWh
0
0
0
0
Settlement Revenue 189,235,565
S 11.25 / Month
$ 0.063138 / kWh
$ 0.053482 / kWh
I,014
$ 4,316,490
6,901,457 S 2,772,694
8,948,341 S 4,293,805
$ 20,166,288 5 7,066,499 $ 19,087 S 27,251,874
$ 12.25 / Month $
$ 0.045384 /kWh
$ 0.137365 / kWh
- $
- $
- $
$
276 622 11 kWh
$ 20 16 8 $ 7 066 499 S 19 087 5 27 1 874
Settlement Revenue $ 20,166,334
$
(46)
Attachment A
Page 2 of 10
Southwestern Public Service Company Docket No. 45524
Revenue at Settlement Rates
Test Year at Test Year at Test. Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REV
Secondary General Voltage
23 SGTX Service Availability Charge 147,051 Bills S 25.60 / Month S 3,764,506
24 Demand Charge - Summer 2,364,212 kW -Mo $ 15.12 / kW -Mo 35,746,883
25 Demand Charge - Winter 3,769,124 kW -Mo S 13.06 1 kW -Mo 49,224,757
26 Energy Charge 2,070,251,694 kWh S 0.007783 /kWh 16,112,769
27 Power Factor Charge - Summa 72,818 kW -Mo S 15.12 / kW -Mo 1,101,004
28 Power Factor Charge -Winter 163,957 kW -Mo S 13.06 /kW -Mo 2,141,277
29 Total 2,070,251,694 kWh S 108,091,196 S 52,883,120 S 312,608 S 161,286,924
30 SGTXTOU Service Availability Charge 117 $ 26.60 / Month S 3,112
31 Demand Charge 252,067 S 10.68 / kW -Mo 2,692,081
32 Energy Charge - On -peak adder 512,650 S 0.131370 / kW -Mo 67,347
33 Energy Charge - All hours 79,321,900 S 0.007783 / kWh 617,362
34 Power Factor Charge 9,898 kW -Mo S 10.68 / kW -Mo 105.709
35 Total 79,321,900 S 3,485,611 S 2,032,875 S 11,978 S 5,530,464
36 SGTXLLF Service Availability Charge 0 $ 26.60 / Month S
37 Demand Charge - All Hours 0 S 5.65 1 kW -Mo
38 Demand Charge - On Peak 0 S 21.12 / kW -Mo
39 Energy Charge 0 S 0.007783 / kWh
40 Power Factor Charge 0 S 5.65 / kW -Mo
41 Total 0 S - S - $ - $
42 Standby Service Availability Charge 0 Bills S 25.60 / Month $
43 Secondary Tran & Dist Standby Capacity Fee - Sumr 0 kW -Mo S 8.24 / kW -Mo
44 Tran & Dist Standby Capacity Fee - Wind 0 kW -Mo S 7.41 / kW -Mo
45 Gen Standby Cap Reservation Fee - Suint 0 kW -Mo S 1.72 / kW -Mo
46 Gen Standby Cap Reservation Fee - Wink 0 kW -Mo S 1.41 / kW -Mo
47 Usage Demand Charge - Summer 0 kW -Mo S 15.12 / kW -Mo
48 Usage Demand Charge - Winter 0 kW -Mo S 13.06 / kW -Mo
49 Power Factor Charge 0 kW -Mo / kW -Mo
50 Energy Charge 0 kWh S 0.007783 / kWh
51 Total 0 kWh S - S - S - S
52 Total Secondary Voltage
2,149,573,594 kWh
S 1111576,807 S 54,915,995 S 324,586 S 16. 17,388
Settlement Revenue S 111,577,623
$ (816)
Attachment A
Page 3 of 10
Southwestern Public Service Company Docket No. 45524
Revenue at Settlement Rates
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - $ FUEL EECRF TOTAL REV
Primary General Service
53 PGTX Service Availability Charge 47,772 Bills $ 58.50 / Month $ 2,794,662
54 Demand Charge - Summer 1,396,442 kW -Mo 5 12.76 / kW -Mo 17,818,605
55 Demand Charge - Winter 2,654,934 kW -Mo S 10.98 / kW -Mo 29,151,176
56 Energy Charge 2,136,433,375 kWh $ 0.005960 /kWh 12,733,143
57 Power Factor Charge- Summa 116,463 kW -Mo $ 12.76 / kW -Mo 1,486,072
58 Power Factor Charge - Winter 184,518 kW -Mo $ 10.98 / kW -Mo 2,026,007
59 Total 2,136,433,375 kWh S 66,009,664 $ 53,587,720 S 525,563 $ 120,122,947
60 PGTXTOU Service Availability Charge 0 $ 5950 / Month $
61 Demand Charge 0 $ 8.82 / kW -Mo $
62 Energy Charge - On -peak adder 0 $ 0.108932 / kW -Mo S
63 Energy Charge - All hours 0 $ 0.005960 / kWh $
64 Power Factor Charge 0 5 8.82 / kW -Mo S -
65 Total 0 $ - $ $ - $
66 PGTXLLF Service AvailabiGryCharge 12 $ 59.50 / Month $ 714
67 Demand Charge - All Hours 25,006 S 5.26 / kW -Mo 131,532
68 Demand Charge - On Peak 219 $ 20.30 / kW -Mo 4,440
69 Energy Charge 948,981 S 0.005960 /kWh 5,656
70 Power Factor Charge 2,688 $ 5.26 / kW -Mo 14,139
71 Total 948,981 $ 156,481 $ $ 233 $ 156,714
72 Standby Service Availability Charge 180 Bills $ 58.50 / Month $ 10,530
73 Primary Tran & Dist Standby Capacity Fee - Sum 3,053 kW -Mo $ 7.05 / kW -Mo 21,524
74 Tran & Dist Standby Capacity Fee - Wind 3,511 kW -Mo $ 6.32 / kW -Mo 22,190
75 Gen Standby Cap Reservation Fee - Sumr 3,053 kW -Mo $ 1.45 / kW -Mo 4,427
76 Gen Standby Cap Reservation Fee - Wintt 3,511 kW -Mo 5 1.19 / kW -Mo 4,178
77 Usage Demand Charge - Summer 2,324 kW -Mo $ 12.76 / kW -Mo 29,654
78 Usage Demand Charge - Winter 7,464 kW -Mo S 10.98 / kW -Mo 81,955
79 Power Factor Charge - Summer Standby 1 1 1 kW -Mo $ 8.50 / kW -Mo 944
80 Power Factor Charge- Winter Standby 135 kW -Mo S 7.51 / kW -Mo 1,014
81 Power Factor Charge- Summer 52 kW -Mo S 12.76 / kW -Mo 664
82 Power Factor Charge - Winter 74 kW -Mo S 10.98 / kW -Mo 813
83 Energy Charge 1,105,940 kWh $ 0.005960 / kWh 6,591
84 Total 1,105,940 kWh $ 184,482 $ 27,756 $ 272 $ 212,511
Southwestern Public Service Company
Revenue at Settlement Rates
Line
No.
85
86
87
88
89
90
91
92
93
94
95
96
97
Description
SAS -4
SAS -8
First 3,500,000 kWh/Month
All Additional Energy
Power Factor Charge
Total
Service Availability Charge
Demand Charge - Summer
Demand Charge - Winter
Energy Charge
Contract Rate - Energy Charge
Power Factor Charge - Summer
Power Factor Charge - Winter
Total
Total Primary Voltage
Billing Units
Base Rate Revenue
at Settkment Base Rates
Rate Revenue -S
42,000,000 kWh $ 0.025510 /kWh $ 1,071,420
99,548,322 kWh $ 0.019838 / kWh 1,974,840
0 kW -Mo 1 kW -Mo 0
141,548,322 kWh
Test Year at
Proposed
Rates
FUEL
Test Year at
Proposed
Rates
EECRF
Attachment A
Page 4 of 10
Docket No. 45524
Test Year at
Proposed
Rates
TOTAL REV
5 3,046,260 $ 3,548,803 S 34,821 $ 6,629,884
0 Bilis S 58.50 / Month $
0 kW -Mo $ 12.76 / kW -Mo
0 kW -Mo $ 10.98 /kW -Mo
0 kWh $ 0.005960 / kWh
42,052,864 kWh $ 0.008464 /kWh
6,433 kW -Mo $ 12.76 / kW -Mo
10,200 kW -Mo $ 10.98 / kW -Mo
42,052,864 kWh
355,935 $
82,085
111,996
S 550,016 5 1,054,733 S 10,345 S 1,615,094
2,322,089,482 kWh
S 69,946,904 5 58,219,012 S 571,234 S 128,737,150
Settlement Revenue $ 69,946,920
$ (16)
Southwestern Public Service Company
Revenue at Settlement Rates
Attachment A
Page 5 of 10
Docket No. 45524
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REV
69 kV Lane General Service - Transmission
98 LGSTTX Service Availability Charge 120 Bills S 710.00 / Month S 85,200
99 Demand Charge -Summer 585,410 kW -Mo $ 11.68 / kW -Mo 6,837,589
100 Demand Charge -Winter 1,185,729 kW -Mo S 8.13 /kW -Mo 9,639,977
101 Energy Charge 1,162,317,602 kWh $ 0.004505 /kWh 5,236,241
102 Energy Charge, inside City Limits 0 kWh $ 0.005798 / kWh -
103 Less: REC Opt -Out 922,931,875 kWh $ (0.000191) / kWh (176,280)
104 Power Factor Charge Summa 47,271 kW -Mo S 11.68 / kW -Mo 552,125
105 Power Factor Charge Winter 79,713 kW -Mo S 8.13 / kW -Mo 648,067
106 Total 1,162,317,602 kWh $ 22,822,919 S 27,399,878 $ - $ 50,222,797
107 Standby Service Availability Charge 12 Bills S 710.00 / Month $ 8,520
108 69kV Transmission Standby Capacity Fee - Sun 40,000 kW -Mo 5 4.54 / kW -Mo 181,600
109 Transmission Standby Capacity Fee - Wit 80,000 kW -Mo S 3.19 / kW -Mo 255,200
110 Gen Standby Cap Reservation Fee - Sumr 40,000 kW -Mo $ 1.78 / kW -Mo 71,200
111 Gen Standby Cap Reservation Fee- Wiote 80,000 kW -Mo $ 1.25 / kW -Mo 100,000
112 Usage Demand Charge - Summer 0 kW -Mo $ 11.68 / kW -Mo -
113 Usage Demand Charge - Winter 0 kW -Mo $ 8.13 / kW -Mo
114 Less: REC Opt -Out 0 $ (0.000191) -
115 Energy Charge 3,110,437 kWh $ 0.004505 /kWh 14,013
116 Power Factor Charge- Summer Standby 4,303 kW -Mo $ 6.32 / kW -Mo 27,195
117 Power Factor Charge - Winter Standby 3,869 kW -Mo $ 4.44 / kW -Mo 17,178
118 Power Factor Charge- Summa 1,271 kW -Mo $ 11.68 / kW -Mo 14,845
119 Power Factor Charge - Winter 6,264 kW -Mo $ 8.13 / kW -Mo 50.926
120 Total 3,110,437 kWh $ 740,678 S 73,366 $ - $ 814,044
121 Total Sub -Transmission Voltage
1,165,428,039 kWh
S 23,563,597 S 27,473245 $ - A_1,036,842
Settlement Revenue $ 23,564,462
$ (865)
Southwestern Public Service Company
Revenue at Settlement Rates
Attachment A
Page 6 of 10
Docket No. 45524
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REV
115 kV+ Large General Service - Transmission
122 LCSTBTX Service Availability Charge 468 Bills 5 710.00 / Month $ 332,280
123 Demand Charge - Summer 2,722,674 kW -Mo S 11.16 / kW -Mo 30,385,042
124 DemandCharge- Winter 5,323,260 kW -Mo $ 7.81 /kW -Mo 41,574,661
125 Energy Charge 4,977,883,034 kWh $ 0.004273 /kWh 21,270,494
126 Energy Charge, Inside City Limits 168,806,020 kWh $ 0.005566 / kWh 939,574
127 Less: AEC Opt -Out 3,431,955,096 kWh S (0.000190) / kWh (652,071)
128 Power Factor Charge - Summer 149,780 kW -Mo $ 11.16 / kW -Mo 1,671,545
129 Power Factor Charge - Winter 269,935 kW -Mo 5 7.81 / kW -Mo 2,108,192
130 Total 5,146,689,054 kWh $ 97,629,717 $ 120,400,364 $ - $ 218,030,081
131 Standby Service Availability Charge 132 Bills $ 710.00 / Month $ 93,720
132 115kV + Transmission Standby Capacity Fee - Sun 117,910 kW -Mo S 4.36 / kW -Mo 514,088
133 Transmission Standby Capacity Fee - Wir 193,325 kW -Mo $ 3.06 / kW -Mo 591,575
134 Gen Standby Cap Reservation Fee - Sumr 117,910 kW -Mo S 1.72 / kW -Mo 202,805
135 Gen Standby Cap Reservation Fee - Winn 193,325 kW -Mo S 1.19 / kW -Mo 230,057
136 Usage Demand Charge - Summer 101,973 kW -Mo S 11.16 / kW -Mo 1,138,019
137 Usage Demand Charge- Winter 230,566 kW -Mc $ 7.81 / kW -Mo 1,800,720
138 Less: REC Opt -Out 0 kWh $ (0.000190) / kWh
139 Energy Charge 175,164,810 kWh $ 0.004273 /kWh 748,479
140 Power Factor Charge - Summer Standby 9,496 kW -Mo $ 6.08 / kW -Mo 57,736
141 Power Factor Charge- Winter Standby 4,636 kW -Mo S 4.25 / kW -Mo 19,703
142 Power Factor Charge- Summer 5,205 kW -Mo S 11.16 / kW -Mo 58,088
143 Power Factor Charge - Winter 9,486 kW -Mo S 7.81 / kW -Mo 74,086
144 Total 175,164,810 kWh S 5,529,075 $ 4,096,619 S - $ 9,625,694
145 Total Backbone Transmission Voltage
5,321,8531064 kWh
S 103 158 792 S 124 496 983 S - $ 227 655 775
Settlement Revenue $ 103,157,995
$ 798
Combined LGS-T Revenue 126,722,389
Settlement Revenue 126,722,457
(68)
Soutbwestern Public Service Company
Revenue at Settlement Rates
Attachment A
Page 7 of 10
Docket No. 45524
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REV
Small Municipal and School Service
146 SMSTX Service Availability Charge 34,080 Bilis $ 13.20 / Month $ 449,856
147 Energy Charge- Summer 5,779,610 kWh $ 0.045136 / kWh 260,868 S 146,606
148 Energy Charge - Winter 12,302,420 kWh S 0.038897 / kWh 478,527 $ 315,717
149 Total 18,082,030 kWh $ 1,189,251 $ 462,323 $ 344 $ 1,651,917
150 SMSTXTOU Service Availability Charge 0 $ 14.20 / Month S
151 Energy Charge - All hours 0 $ 0.033458 / kWh - S
152 Energy Charge - On -peak adder 0 S 0.117987 / kWh - S
153 Total 0 S - $ S - S
154 Total Small Municipal and School Service 18,082,030 kWh S 1,189,251 S 462,323 S 344 S 1,651,917
Settlement Revenue S 1,189,249
$ 2
Southwestern. Public Service Company
Revenue at Settlement Rates
Attachment A'
Page 8 of 10
Docket No. 45524
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - $ FUEL EECRF TOTAL REV
Large Municipal Service
155 LMSTX SEC Service Availability Charge 11,160 Bills $ 25.90 / Month S 289,044
156 Demand Charge - Summer 184,123 kW -Mo $ 10.87 / kW -Mo 2,001,415
157 Demand Charge - Winter 314,750 kW -Mo $ 8.90 / kW -Mo 2,801,274
158 Energy Charge 146,359,091 kWh $ 0.007692 / kWh 1,125,794
159 Power Factor Charge - Summer 4,677 kW -Mo S 10.87 / kW -Mo 50,836
160 Power Factor Charge - Winter 7,837 kW -Mo $ 8.90 / kW -Mo 69,752
161 Total 146,359,091 kWh S 6,338,115 S 3,739,743 5 (38,932) S 10,038,926
6,338.130
162 LMSTX SEC Service Availability Charge 0 Bills $ 26.90 / Month $ -
163 TOU Demand Charge 0 kW -Mo $ 7.30 / kW -Mo -
164 Energy Charge - On Peak Adder 0 kWh 5 0.122527 / kWh
165 Energy Charge - All Hours 0 kWh $ 0.007692 / kWh
166 Power Factor Charge 0 kW -Mc $ 7.30 / kW -Mo -
167 Total 0 $ S - S - $
168 LMSTX PRI Service Availability Charge 144 Bills $ 25.90 / Month $ 3,730
169 Demand Charge - Summer 33,566 kW -Mo $ 10.73 / kW -Mo 360,167
170 Demand Charge - Winter 51,865 kW -Mo $ 8.80 / kW -Mo 456,409
171 Energy Charge 24,499,480 kWh $ 0.007573 /kWh 185,535
172 Power Factor Charge - Summer 859 kW -Mo $ 10.73 / kW -Mo 9,220
173 Power Factor Charge - Winter 1.307 kW -Mo 5 8.80 / kW -Mo 11,502
174 Total 24,499,480 $ 1,026,563 $ 614,091 $ (6,517) S 1,634,137
$ 1,026,526
175 LMSTX PRI Service Availability Charge 0 Bills $ 26.90 / Month $
176 TOU Demand Charge 0 kW -Mo S 7.34 / kW -Mo
177 Energy Charge - On Peak Adder 0 kWh $ 0.120055 / kWh
178 Energy Charge - All Hours 0 kWh $ 0.007573 / kWh
179 Power Factor Charge 0 kW -Mo $ 7.34 / kW -Mo
180 Total 0 S - S $ - $
181 Total Large Municipal Service 170 5 71 kWh S 7 64 677 S 4 53 834 S 4 448 S 11 673 063
Settlement Revenue $ 7,364,656
$ 21
Attachment A
Page 9 of 10
Southwestern Public Service Company Docket No. 45524
Revenue at Settlement Rates
Test Year at Test Year at Test Year at
Bax Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REV
Large School Service
182 LSSTX Service Availability Charge 8,868 Bills $ 31.30 1 Month 5 277,568
183 SEC Demand Charge- Summer 259,298 kW -Mo S 13.66 / kW -Mo 3,542,006
184 Demand Charge - Winter 446,872 kW -Mo $ 11.21 / kW -Mo 5,009,439
185 Energy Charge 173,163,600 kWh 5 0.009577 /kWh 1,658,388
186 Power Factor Charge - Summer 3,616 kW -Mo 5 13.66 / kW -Mo 49,400
187 Power Factor Charge - Wmter 3,262 kW -Mo S 11.21 / kW -Mo 36,569
188 Total 173,163,600 kWh $ 10,573,370 S 4,425,781 $ 206,584 $ 15,205,735
10.573,395
189 LSSTXTOU Service Availability Charge 0 Bills S 32.30 / Month $ -
190 SEC Demand Charge 0 kW -Mo S 9.67 / kW -Mo
191 Energy Charge - On Peak Adder 0 kWh $ 0.142949 / kWh -
192 Energy Charge - All Hours 0 kWh $ 0.009577 / kWh - S
193 Power Factor Charge 0 kW -Mo S 9.67 / kW -Mo
194 Total 0 S - $ - $ - $
195 LSSTX Service Availability Charge 48 Bills 5 3L30 / Month S 1,502
196 PRI Demand Charge - Summer 3,533 kW -Mo $ 11.97 / kW -Mo 42,290
197 Demand Charge - Winter 5,441 kW -Mo S 9.85 / kW -Mo 53,590
198 Energy Charge 2,800,918 kWh S 0.008990 /kWh 25,180
199 Power Factor Charge - Summer 49 kW -Mo S 11.97 / kW -Mo 592
200 Power Factor Charge - Winter 40 kW -Mo S 9.85 / kW -Mo 397
201 Total 2,800,918 kWh S 123,550 S 70,221 S 3,341 S 197,112
123,547
202 LSSTXTOU Service Availability Charge 0 Bills S 32.30 S -
203 PRI Demand Charge 0 kW -Mo S 7.59
204 Energy Charge - On Peak Adder 0 kWh $ 0.140525 -
205 Energy Charge -All Hours 0 kWh $ 0.008990 - S
206 Power Factor Charge 0 kW -Mo / kW -Mo -
207 Total 0 S - $ $ - S
208
209 Total Large School Service 175,964,518 kWh S 10,696,920 S 4,496,002 S 209 926 S 15 40 848
Settlement Revenue S 10,696,942
$ (22)
Southwestern Public Service Company
Revenue at Settlement Rates
Attachment A
Page 10 of 10
Docket No. 45524
Test Year at Test Year at Test Year at
Base Rate Revenue Proposed Proposed Proposed
Line at Settlement Base Rates Rates Rates Rates
No. Description Billing Units Rate Revenue - S FUEL EECRF TOTAL REY
Area Lighting Service
210 Flood Ltg. Light Charge
211 Energy Charge
212 Per Book - Base Rate Revenue
213 Guard Ltg. Light Charge
214 Energy Charge
215 Per Book - Base Rate Revenue
216 SA -810 Light Charge
217 Energy Charge
218 Per Book - Base Rate Revenue
219 Total Area Lighting Service
Street Lighting Service
46,666 Ltg-Mo various / Ltg-Mo 5 1,263,201
11,334,807 kWh $ - / kWh
11,334,807 kWh
$ 1,263,201 S 289,763 $ - $ 1,552,964
225,008 Ltg-Mo various / Ltg-Mo S 2,938,918
13,332,134 kWh $ - /kWh -
13,332,134 kWh S 2,938,918 5 340,823 $ - 5 3,279,741
579 Ltg-Mo various / Ltg-Mo S 5,210
50,424 kWh S - / kWh -
50,424 kWh
S 5,210 5
1,289 S - $ 6,499
2 717 65 kWh S 4 207 29 S 63 875 5 $ 4 839 ' 4
Settlement Revenue $ 4,207,311
18
220 SL Light Charge 360,785 Ltg-Mo various / Ltg-Mo $ 3,888,779
221 Energy Charge 33,919,228 kWh $ - / kWh -
222 Per Book - Base Rate Revenue 33,919,228 kWh
223 Total Street Lighting Service 33,919,228 kWh
Sign Lighting Service
S 3,888,779 S 867,111 $ - S 4,755,890
S 3,888,779 S 867,111 S - S 4,755,890.
224 SA -805 Minimum Charge 0 Meters 5 - / Meter $
225 Energy Charge 107,280 kWh S 0.032401 /kWh
226 Per Book - Base Rate Revenue 107,280 kWh
3,476
$ 3,476 5 2,743 $ - $ 6,219
227 Total Sign Lighting Service 107,280 kWh S 3,476 S 2,743 S - S 6 219
Settlement Street and Sign Lighting Revenue 3,892,943
S (688)
Total Company Retail Base Rate Revenue:
228 Total at Settlement Rates 14 077,714,107 kWh S 544,999 $ 3 769,056 S 2,695,284 S 89 463,739
Total Settlement Base Rate Revenue Requirement 5 545,000,000
X l Energy
SGU1'l1WEST1! U PUItfc SERVICE
ELECTRIC TARIFF
Attachment B
Page 1 of 75
43
Section No. I -S
Sheet No. I-1
Revision No. 31 T
Page 1 of 1
TABLE OF CONTENTS
SECTION IITLE SECTION SHEET
I Table of Contents I 1
II Description of Operations II 1
III Service Area List III 1
1V Rate Schedules IV 1-211 T
V Service Rules and Regulations V 1-32
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000038
44
Southwestern Public Ser, ce Company
Xcel'Energy
I sir ■aTa�P
Map Updated; 1/Z712016
Transmission Line
Voltage (kV)
- 345
230
- 115
- 86
w
min
New Mexico...-Itiff 1
c4;04' da
Attachment B
Page 2 of 75
Kan- naae
k4
-
O 20 40 80
Mlles
REGIONAL VICE PRESIDENT BATES AND
REGULATORY AFFAIRS
000039
XCei Energy'
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 3 of 75
45
Section No. 111
Sheet No. II1-1
Revision No. 9
Page 1 of 1
LIST OF COUNTIES AND CITIES PROVIDED ELECTRIC UTILITY
SERVICES BY SOUTHWESTERN PUBLIC SERVICE COMPANY
COUNTY ULM WITHIN COUNTY
Armstrong Claude
Bailey Muleshoe
Briscoe Silverton
Carson Groom, Panhrr+dle, Skellytown, White Deer
Castro Dimmitt, Hart
Cochran Morton, Whiteface
Crosby Crosbyton, Lorenzo, Ralls
Dallam Dalhart
Dawson
Deaf Smith Hereford
Donley
Floyd
Gaines
Garza
Gray
Hale
Hansford.
Hartley
Hemphill
Hockley
Hutchinson
Lamb
Lipscomb
Lubbock
Lynn
Moore
Oe iltree
Oldham
Panner
Potter
Randall
Roberts
Sherman
Swisher
Terry
Wheel
Yoakum
Floydada, Lockney
Seminole, Seagraves
Post
Lefors, McLean, Pampa
Abernathy, Hale Center, Petersburg, Plainview
Gruver, Spearman
Channing, Dalhart
Canadian
Anton, Levelland, Ropesvile
Borger, Flitch, Stinnett
Amherst, Barth, Littlefield, Olton, Springlake, Sudan
Booker, Darrouzett, Follett, Higgins
Melon, Lubbock, New Deal, Shallowater, Slatan, Wolfforth
Tahoka, Wilson
Cactus, Dumas, Sunray
Perryton
Adrian, Vega
Bovine, Friona, Farwell
Amarillo
Amarillo, Canyon, Lake Tanglewood, Timbercreek;
Palisades
Miami
Stratford
Happy, Kress
Meadow, Wellman
Mobeetie, Wheeler
Denver City
REGIONAL VICE, PRESIDENT RATES AND
REGULATORY AFFAIRS
000040
46
XceIEnergy
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 4 of 75
Section No. IV
Sheet No. IV -1
Revision No. 117
Page 1 of 5
T�
Sheet
No.
TABLE OF SERVICE SCHEDULES
Revision
No.
Type of Service
Territory
IV -3
1V-18
IV -56
20
20
17
Residential Service
Secondary General Service
Service Agreement Summary
Bishop Hills Property Owners
Amarillo College
Chase Bank Tower
IV -61 14 Service Agreement Summary
Canadian River Municipal
Water Authorities
IV -65 19 Guard Lighting Service
IV -69 44 Fuel Cost Recovery Factor
IV -77 11 Electric Service to a Qualifying
Facility of Aggregate Generation
Capacity of 100 K W or Less
Texas service territory
Texas service territory
Potter County
Amarillo
Amarillo
Potter, Carson, Roberts &
Hutchison Counties
Texas service territory
Applicable to rate schedules
where indicated
Texas service territory
IV -86 12 Energy Purchase From a Texas service territory
Qualifying Facility of Aggregate
Generating Capacity of 100 K W
Or Less
T
T
T
T
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000041
XcelEnergySM
SOUTHWESTERN PUBLIC SERvtCf
ELECTRIC TARIFF
Attachment B
Page 5 of 75
47
Section No. IV
Sheet No. W-1
Revision No. 117 T
Page 2 of 5
Sheet
No.
TABLE OF SERVICE SCHEDULES
Revision
No.
Type of Service
Territory
IV -91 16
W-98 14
W-99 14
W-108 12
IV -109 13
IV -117 4
Municipal and State Street
Lighting Service
Miscellaneous Service Charge
Service Agreement Summary
Orion Engineered Carbons
Large General Service
Transmission
Service Agreement Summary
WRB Refining L.P.
Avoided Energy Cost
Non -Firm Purchases from
Qualifying Facilities
IV -118 10 Flood Light Systems
IV -144 3 Service Agreement Summary
Highway Sign Lighting
W-150 9 Restricted Outdoor Lighting
Service
Texas service territory
Texas service territory
Hutchinson County
T
Texas service territory T
WRB Reining L.P. Refinery & T
Chemical Complex near Borger
Texas service lenitory
Texas service territory
Amarillo
Former TNP Panhandle
service territory
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000042
48
XcelEnewv
$01 rliWE$TERN PUJtIC SP*Y?CE
ELECTRIC TARIFF
Attachment B
Page 6 of 75
Section No. IV
Sheet No. W-1
Revision No. 117 T
Page 3 of 5
Sheet
No.
TABLE OF SERVICE SCHEDULES
Revision
No.
Type of Service
Territory
W-152 2
W-159 5
IV -172 8
IV -173 9
IV -174 8
IV -175 9
IV -177 4
IV -179 8
IV -180 8
IV -181 8
W-182 9
State University Discount
Rate Rider
Distributed Generation
Interconnection
Small General Service
Primary General Service
Small Municipal and School
Service
Large Municipal Service
Interruptible Credit Option
Primary QF Standby Service
Secondary QF Standby
Service
Transmission QF Standby
Service
Large School Service
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
T
T
T
T
T
T
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000043
re?
XCel Energg
SOurxwUUTERN Iustre MIME
ELECTRIC TARIFF
Attachment B
Page 7 of 75
49
Section No. IV
Sheet No. IV -1
Revision No. 117
Page 4 of 5
T
Sheet
No.
TABLE OF SERVICE SCHEDULES
Revision
No.
Type of Service
Territory
IV -183 8
1V-188 3
IV -189 3
IV -192 1
IV -193 1
IV -194 1
IV -195 6
IV -204 Orig
Transmission QF Non -Firm
Standby Service
Residential Controlled Air
Conditioning and Water
Heater Rider
Commercial and Industrial
Controlled Air Conditioning
Rider
Municipal Franchise Fee
Peak Day Partner
Interruptible Credit Option
(Summer Only)
Energy Efficiency Cost
Recovery Rider
Discount For Veterans Severely
Burned in Combat
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
Texas service territory
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000044
50
XceI Energ '
$OU1THWSSTERN PUBLIC SERVJCE
ELECTRIC TARIFF
Attachment B
Page 8 of 75
Section No. W
Sheet No. W-1
Revision No. 117 T
Page 5 of 5
TABLE 01? SERVICE SCHEDULES
Sheet Revision
No. No. Type of Service Territory
W-205 1 SG/PG Time of Use Texas service territory
W-206 1 SG/PG Low Load Factor Texas service territory
IV -211 Orig. Rate Case Expense Rider Texas service territory
T
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000045
"0,
XtelEnergy�
SOBUHWSSTERN PUBLIC SUMS
ELECTRIC TARIFF
Attachment B
Page 9 of 75
51
Section No. IV
Sheet No. IV -3
Revision No. 20
Page l of 3
RESIDENTIAL SERVICE
APPLICABILITY: To residential Customers for electric service used for domestic purposes in private
residences and separately metered individual apartments, when all service is supplied at one point
of delivery and measured through one kilowatt-hour meter, where facilities of adequate capacity
and suitable voltage are adjacent to the premises to be served. Single phase motors that do not
exceed 10 horsepower individual capacity may be served under this rate.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $10.00 per month.
Energy Charge:
$0.078572 per kWh for all kWh used per month during each summer month
$0.068353 per kWh for all kWh used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
ALTERNATE EXYERIMENTAL TIME OF USE RIDER
RATE: Service Availability Charge: $10.50 per month.
Energy Charge:
$0.058183 per kWh for all kWh used during all hours, PLUS
$0.124929 per kWh for all kWh used during On -Peak Hours R
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Availability limited to a maximum of 100 customers that qualify for service under Residential
Service. Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June throngli September. The Off -Peak period shall be all other hours
not covered in the On -Peak period.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000046
52
AcelEneigyM
90U?HWISTFRN PUBLIC SUVal i
ELECTRIC TARIFF
Attachment B
Page 10 of 75
Section No. IV
Sheet No. IV -3
Revision No. 20
Page 2 of 3
RESIDENTIAL SERVICE
ELECTRIC SPACE HEATING RIDER
RATE: Service Availability Charge: $10.00 per month.
Energy Charge:
$0.078572 per kWh for all kWh used per month during each summer month
$0.048582 per kWh for all kWh used per month during each winter month
Available to Residential Service customers who predominately use electric space heating in private
residences and separately metered individual apartments. Electric space heating includes
permanently installed space heating equipment in regular use, including heat pumps and electric
resistance heating, excluding bathroom heaters. Not available to customers establishing service
on or after January 1, 2016.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kilowatt-hour of the above rate shall
be increased by the applicable fuel cost recovery factor per kilowatt-hour as provided in PUCT
Sheet IV -69. This rate schedule is subject to other applicable rate adjustments.
AVERAGE MONTHLY PAYMENT: Upon request, any residential customer may be billed monthly on
a levelized payment plan. A Customer's monthly payment amount is calculated by obtaining the
most recent twelve months of actual consumption and dividing that amount by twelve, and applying
Company's current rates to the average kWh consumption. The account will be trued -up every
twelve months. The true -up amount is equal to the difference between the total levelized payments
during the previous twelve months and the actual amount billed during the same period.
CHARACTER OF SERVICE: A -C; 60 hertz; single-phase 120/240 volts; where available on
secondary, three phase 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
TERMS OF PAYMENT: Net in 16 days after mailing date. If the sixteenth day falls on a holiday or
weekend, the due date will be the next work day.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000047
ra,
X l Energyy
SOUTHWESTERN PUBLIC SEftYZCE
ELECTRIC TARIFF
Attachment B
Page 11 of 75
53
Section No. IV
Sheet No. N-3
Revision No. 20
Page 3 of 3
RESIDENTIAL SERVICE
RULES, REGULATIONS AN)) CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in Company's Rules, Regulations, and Conditions of
Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000048
54
v' XcelEnergr
SCPUTHWES11191 00SLIC Se*VICE
ELECTRIC TARIFF
Attachment B
Page 12of75
Section No. W
Sheet No. W-18
Revision No. 20 T
Page 1 of 2
SECONDARY GENERAL SERVICE
APPLICABILITY: To all commercial and industrial electric service supplied at secondary voltage at
one Point of Delivery and measured through one meter, where facilities of adequate capacity
and suitable voltage are adjacent to the premises to be served, in excess of 10 kW of demand.
Each year, Company will review the demand of all Customers receiving service under this
tarig If the average of Customer's twelve monthly demands in the immediately preceding
calendar year does not exceed 10 kW, then Customer is not eligible to continue receiving
service under this tariff.
Not applicable to standby, supplementary, resale or shared service, or service to oil and natural
gas production Customers.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $25.60 per month. R
Energy Charge: $0.007783 per kWh for all kWh used during the month
Demand Charge:
$15.12 per kW of demand used per month during each summer month I
$13.06 per kW of demand used per month during each winter month I
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
DEMAND: Company will furnish, at Company's expense, the necessary metering equipment to
measure the Customer's kW demand for the 30 -minute period of greatest use during the month.
In no month, shall the billing demand be greater than the kW value determined by dividing the
kWh sales for the billing period by 80 hours.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000049
XceI Energ
$OUtHiWES7DN IUGt(C MY)CB
ELECTRIC TARIFF
Attachment B
Page 13 of 75
Section No. W
Sheet No. W-18
Revision No. 20
Page 2 of 2
SECONDARY GENERAL SERVICE
POWER FACTOR ADJUSTMENT (cont.):
Power Factor Adjustment Charge = Demand charge x ((0.95 ? customer's power factor x kW
demand) — kW demand)
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh shall be increased by the
applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate
schedule is subject to other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard
secondary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations and
Conditions of Service on file with the Public Utility Commission of Texas. A Contract may be
required by the Company to be executed prior to extending service if Customer's load is expected
to be greater than 200 kW. The contract term shall contain a minimum contract period with an
automatic renewable provision from year to year thereafter.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000050
55
56
10, XcelEnengr
SOUTHWEStERN SUV1Ct
ELECTRIC TARIFF
Attachment B
Page 14 of 75
Section No. IV
Sheet No. IV -56
Revision No. 17 T
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Bishop Hills Property Owners, Amarillo, Texas.
RATE: Each 7,000 lumen mercury vapor post top light (a3 $8.07 per month.
AGREEMENT WITH: Amarillo College, Amarillo, Texas.
RATE: Each 7,000 lumen wood pole overhead mercury vapor street light (4) $8.07 per month.
Each 20,000 lumen steel pole underground mercury vapor street light (two lamps per pole) (Qa
$19.86 per month.
FUEL COST RECOVERY: The charge per kWh of the above rate chnll be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet N-69.
Pursuant to the 2005 Energy Policy Act, mercury vapor lamp ballasts chall not be manufactured
or imported after January 1, 2008. When Company's inventory of mercury vapor ballasts and
Lamps is exhausted, Customers will be given the option of having the lighting facilities removed,
or replaced with another type of lamp at the applicable rate for the replacement lamp.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000051
XCe Energy
SOUTNWESIERN HUBite SERvICE
ELECTRIC TARIFF
Attachment B
Page 15 of 75
57
Section No. IV
Sheet No. IV -61
Revision No. 14
Page 1 of 2
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Canadian River Municipal Water Authority (CRMWA)
POINTS OF SERVICE: Pumping facilities related to CRMWA's transport and production of water to
CRMWA's member cities from Lake Meredith and groundwater in Roberts County, Texas.
RATE: The base rate for firm and interruptible service to CRMWA is:
$0.025510 per kWh for the first 3,500,000 kWh used per month.
$0.01983 8 per kWh for all additional energy used per month.
INTERRUPTISILTTY: When a scheduled interruption is requested in any month by Company,
CRMWA will interrupt all load at Pump Station Nos. 1 — 4, in excess of two pumping units at
each station, and will also interrupt all load at Pump Station Nos. 21 and 22, in excess of one
pumping unit at each station, and will interrupt all Load in the waterfield, including Booster
Stations 31 and 32 and the wells associated with these stations, with the exception of the wells
feeding Pump Station No. 21 directly, or which can be delivered to Pump Station No. 21 by
gravity flow. Uninterrupted wells will not have a connected load in excess of 2134 kW. Pump
Station Nos. 5 and 6 are not subject to interruption. Normal interruptions of load shall not
exceed 60 hours in any month except in an extreme emergency. If a scheduled interruption of
load causes an inability of CRMWA to maintain sufficient water storage, pumps may be
restarted with two-hour notice to the Company. Energy served during this period will be billed
at the rate for the first energy block.
NOTICE OF INTERRUPTION: Company will give notice of need for interruption at least two hours
before the interruption is required.
MUL+'L COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
POWER FACTOR Synchronous motors will be installed on each pumping unit in CRMWA's
pumping plant Nos. 1 - 4, and will be operated at Unity Power Factor. Customer agrees to
maintain a power factor of at least 0.95 on pumping units 21 and 22.
I
I
‘,„_°,40)
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000052
58
XceI nergy
SOUTHWESTERN FUSLrC SERVICE
ELECTRIC TARIFF
Attachment 13
Page 16 of 75
Section No. IV
Sheet No. IV -61
Revision No. 14 T
Page 2 of 2
SERVICE AGREEMENT SUMMARY
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirtyminute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Applicable Primary General Service Demand charge x
((0.95 T customer's power factor x kW demand) — kW dernand)
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If
the sixteenth day falls on a holiday or weekend, the due date will be the next workday.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000053
X iEne -
SOUtaliVEStEXN HJ»LIC SS>tYICE
ELECTRIC TARIFF
Attachment 13
Page 17 of 75
Section No. IV
Sheet No. IV -65
Revision No. 19
Page 1 of 2
GUARD LIGHTING SERVICE
APPLICABILITY: Under contract for night outdoor lighting service where facilities of adequate
capacity and suitable voltage are adjacent to the premises to be served.. This tariff is closed to
new Customers as of September 1, 2000 in accordance with the Public Utility Commission of
Texas Order in Docket No. 21190, and no additional lights will be installed for existing
Customers. Ownership of existing Guard Lights may be transferred to a new Customer if the
property that the Guard Light serves is sold to the new Customer and the new Customer agrees to
the monthly charge for the applicable Guard Light.
Pursuant to the Federal Energy Policy Act of 2005, mercury vapor lamp ballasts shall not be
manufactured or imported after January 1, 2008. When Company's inventory of mercury vapor
ballasts and lamps is exhausted, Customers will be given the option of having the lighting
facilities removed, or replaced with another type of light at the rate for the replacement light.
TERRITORY: Texas service territory.
RATE: Each 15,000 lumen high pressure sodium (HPS), wood pole, overhead bracket type light cQ
$13.00 per month.
Each 7,000 lumen mercury vapor (MV), wood pole, overhead bracket type light ® $13.39 per
month.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If
service is billed on a residential bill, the late payment charge will not be imposed If the sixteenth
day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF ENERGY USE: 15,000 lumen HPS lamp uses 56 kWh per month; 7,000
lumen MV lamp uses'68 kWh per month.
1+'U.EL COST RECOVERY: The charge per kWh of the above rate chill be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. However, Guard Light
Service provided by Company which is connected to a circuit previously metered by Company
for other electric service shall not have the above rate increased by the applicable fuel cost
recovery factor.
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000054
59
60
Xce/ Energy
SOUTHWESTERN PURifC SERVICE
ELECTRIC TARIFF
Attachment B
Page 18 of 75
Section No. W
Sheet No. W-65
Revision No. 19
Page 2 of 2
GUARD LIGHTING SERVICE
CONDITIONS OF SERVICE: Company will construct, own, operate and maintain, on Customer's
premises, the required number of 15,000 lumen, 150 watt, HPS overhead lights, and/or the
required number of 7,000 lumen, 175 watt, MV overhead lights, mounted on a metal bracket,
photo -electrically controlled, installed on Company's service pole, on a separate 30 foot pole, or
on any suitable mounting device belonging to the Customer, having a secondary line span not to
exceed 150 feet in length. Lights will not be installed on any mounting device which the
Company deems, in its sole discretion, unsafe or unsuitable for this purpose.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase; 120 or 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this
schedule is subject to the terms and conditions set forth in Company's Rules, Regulations, and
Conditions of Service on file with the Public Utility Commission of Texas.
�a-
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000055
XceIEnerg
9OUTOWES7D tf PLPBUC $E1VJCE
ELECTRIC TARIFF
Attachment B
Page 19 of 75
61
Section No. IV
Sheet No. IV -91
Revision No 16 T
Page 1 of 5
MUNICIPAL AND STATE STREET LIGHTING SERVICE
APPLICABILITY: To Municipal and State of Texas Agency Customers for street lighting service where
facilities of adequate capacity and suitable voltage are adjacent to the point of service.
Pursuant to the Federal Energy Policy Act of 2005, mercury vapor (MV) lamp ballasts shall not be
manufactured or imported after January 1, 2008. When Company's inventory of MV ballasts and
lamps is exhausted, Customers will be given the option of having the lighting facilities removed, or
replaced with another type of light at the rate for the replacement light.
TERRITORY: Texas service territory.
RATE: The charge per lamp per month shall be in accordance with the following rates:
RESIDENTIAL AREAS
LAMP SIZE LAMP TYPE WOOD POLE STEEL POLE
Lumen Overhead (2) Overhead Underground (1)
7,000 MV $ 6.64 $9.20 $ 10.46 R
15,000 HPS 12.63 12.63 12.63 R
COMMERCIAL AREAS AND TRAFFIC ARTERIES
LAMP SIZE LAMP TYPE WOOD POLE STEEL POLE
Lumen Overhead Overhead Underground (1)
20,000 MV $11.14 $15.35 $20.89 R
35,000 MV 15.46 19.55 25.37 R
50,000 MV 18.82 23.20 28.81 R
15,000 HPS -12.62 12.62 12.62 R
27,500 HPS 24.35 2435 24.35 R
EXISTING FEEDER NEW STREET LIGJJT CIRCUM
CIRCU11 (50' POLES) (45'WOOD POLES OVERHEAD)
50,000 HPS $26.84 $31.71 R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000056
62
re), XcelEnergr
SUUTNWUS1ERN PUBLIC SFkvICE
ELECTRIC TARIFF
Attachment B
Page 20 of 75
Section No. IV
Sheet No. IV -91
Revision No. 16
Page 2 of 5
MUNICIPAL AND STATE STREET LIGHTING SERVICE
LED MUNICIPAL STREET LIGHT RATES
LAMP LAMP
SIZE TYPE
4,000 LED $ 8.30
6,000 LED $10.94
14,000 LED $16.12
25,000 LED $23.30
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added after 16 days if the
sixteenth day fells on a holiday or weekend, the due date will be the next work day.
CONDITIONS OF SERVICE: The foregoing rates include the furnishing by Company of the electric
energy necessary to operate the municipal street lighting system, the replacement of lamps, and the
normal maintenance of fixtures, wires, transformers and all other component parts of the street
lighting systems, as such replacements and maintenance become necessary. In the event
maintenance and/or lamp and glassware replacements become excessive due to vandalism or
similar causes, Company will notify the City and the City will exert whatever means are at its
disposal in the form of law enforcement agencies or other protective measures to eliminate
destruction of street lighting equipment. If such vandalism.persists, Company reserves the right to
remove street lights.
Company will install, own, operate and maintain the municipal street lighting system. If, for any
reason, Company is unable to continue service of particular equipment, said equipment will, at the
City's option, be removed by Company or replaced by Company with currently available
equipment, and the City will pay the appropriate rate for new equipment.
Street light burning time will be from approximately one-half hour after sunset to approximately
one-half hour before sunrise.
In the event the City requests that an operable non -LED street light lamp and fixture be replaced
with an LED street light lamp and fixture, the City will pay abandonment and removal costs to
Company, at the time of removal of such equipment from service based on the table shown below:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000057
xc. Energy*
BOUDNWISnERk PUBLIC SEIVICE
ELECTRIC TARIFF
Attachment B
Page 21 of 75
63
Section No. IV
Sheet No. IV -91
Revision No. 16
Page3 of5
T
MUNICIPAL AND STATE STREET LIGHTING SERVICE
Years Installed
More Than Less Than
Light Type Lumen One Year One Year
All MVs $ 244.12 N/A
HPS 15,000 $ 261.22 $ 289.81
HPS 25,000 $ 254.39 $ 293.28
HPS 50,000 $ 261.22 $ 351.93
STATE OWNED FREEWAY LIGHTING SYSTEM:
Available to all state-owned and city maintained street and highway lighting and incidental safety
lighting that is photocell controlled. The state-owned highway lighting rates do not include any
maintenance service by Company.
Lumen Lamp Type
20,000 MV
27,500 HPS
50,000 BPS -400 watt
Underground
$7.94
5.62
7.07
(1) Applicable to bath bracket -type and post -top luminaires.
(2) Underground option is available where facilities of correct voltage are readily available and
customer agrees to pay a non-refundable contribution m aid of construction equal to the total
cost of installation in accordance with the standard line extension policy.
CUSTOMER -OWNED STREET LIGHTING OPTION:
AVAILABILITY: For year round illumination of public streets and parkways by electric lamps mounted
on standards where Customer owns Company approved street light systems complete with
standards, luminaries with globes, lamps, and other appurtenances, together with all necessary
cables extending between standards and to the point of connection to Company's facilities as
designated by Company.
Customer is responsible for maintaining customer -owned street light systems.
N
N
R
R
R
N
N
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000058
64
Xc,IElgg"
Sou1NWEEtE114 PUSLIC .8EAY?CE
ELECTRIC TARIFF
Attachment B
Page 22 of 75
Section No. IV
Sheet No. IV -91
Revision No. 16 T
Page 4 of 5
MUNICIPAL AND STATE STREET LIGHTING SERVICE
RATE: The monthly charge to provide energy and services for customer -owned lighting facilities is
$0.042684 per kWh per month at locations acceptable to the Company. Since li_ ting installations
are generally unmetered, the monthly kWh shall be determined by the Company prior to use of
Company facilities and based upon the type of lamp installed in the customer -owned light facility.
DETERMINATION OF ENERGY IISE:
LED
4,000 lumen lamp use 13 kWh per month
6,000 lumen lamp use 21 kWh per month
14,0001umen lamp use 51 kWh per month
25,000 lumen lamp use 81 kWh per month
KWh for other light types and sizes as determined by Company prior to use of Company facilities by the
lighting facility.
MERCURY VAPOR
7,000 lumen Iamp uses 68 kWh per month
20,000 lumen lamp uses 151 kWh per month
35,000 lumen lamp uses 257 kWh per month
50,000 lumen lamp uses 363 kWh per month
100 watt lamp uses 42 kWh per month
1,000 watt lamp uses 363 kWh per month
HIGH PRESSURE- SODIUM
15,000 lumen lamp uses 56 kWh per month
27,500 lumen lamp uses 97 kWh per month
50,000 Iumen lamp uses 159 kWh per month
400 watt lamp uses 159 kWh per month
¥ULL COST RECOVERY: The charge per kilowatt-hour of the above rate chill be increased by the
applicable fuel cost recovery factor per kilowatt-hour as provided in PUCT Sheet IV -69.
If any street light is permanently removed from service at the City's request, the City will pay to
Company, at the time of removal from service of such light, the original cost of the equipment
taken out of service, less depreciation of four percent per year. If any street light is removed from
service temporarily (at least two months) at the City's request, the monthly rate for the light during
temporary disconnection will be the base charge per lamp as stated above. Fuel cost recovery will
not be charged or credited on any temporarily disconnected street light
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000059
/e")../
XCelEnergr
SOUtH*SSrtRN Pbet►C S€Rv1tf
ELECTRIC TARIFF
Attachment B
Page 23 of 75
65
Section No. IV
Sheet No. IV -91
Revision No. 16
Page 5 of 5
T
MUNICIPAL AND STATE STREET LIGHTING SERVICE
STREET LIGHT OUTAGE REPAIR SPS shall patrol all streetlights on a quarterly basis. SPS will
track street light outage information and report performance to any requesting city and/or state
agency within thirty (30) days after each quarterly patrol is completed. In addition, SPS will
implement a formal system to track street light outage Performance and will track trouble reports
submitted by: (a) Customers; (b) employees; (c) municipalities; and (d) routine SPS patrols. SPS
shall use best efforts to repair all street light trouble orders, exclusive of freeway lights, within
seven calendar days. If a municipal street light, exclusive of freeway lights, is not repaired within
seven (7) calendar days after SPS receives notice of the specific streetlight trouble, SPS shall issue
a credit to the Customer's bill equal to one month's charges for the respective street light. Further,
SPS shall issue an additional credit to the Customer equal to a month's charges for each such
streetlight for each additional seven (7) calendar -day delay in completing repairs for each affected
streetlight. Freeway lights shall be repaired in a reasonable amount of time taking into account
coordination with state transportation agencies and arranging traffic control for public safety while
SPS agents repair freeway lights. SPS shall prepare a mitten street light performance plan to
include periodic patrolling, advanced re-lamping, painting; and glassware cleaning, and shall
provide any city and/or state agency an annual streetlight: performance report showing the number
of streetlights for which SPS has issued credits, including identification of those streetlights for
which SPS issued multiple credits, and amounts of said credits. The streetlight performance plan
shall be completed by December 1 of each year and the streetlight performance report shall be
completed by the end of the First Quarter of the succeeding year to which the report applies.
Upon request, SPS shall also provide a detailed report to any requesting city and/or state agency
identifying the streetlights for which a trouble report was received, the date the trouble report was
received, the commitment date provided by SPS stating when the trouble would be repaired, and the
date the trouble was repaired. Notwithstanding the above conditions, both Customer and SPS
realize that storm outages and other items outside of the control of SPS may affect repair times for
street light outages. SPS shall not be required to provide credits to Customers for delayed repairs
caused by, or during, such events.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
RULES REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terrns and conditions set forth in the Company's Rules, Regulations, and
Conditions of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000060
66
Xcel Energy -
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 24 of 75
Section No. IV
Sheet No. IV -99
Revision No. 14 T
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Orion Engineered Carbons (formerly Degussa; or J.M. Huber Corp.)
POINT OF SERVICE: Vicinity of Borger, Texas
RATE: The -Contract rate of $0.008464 per kilowatt-hour (kWh) used per month.
g during any billing month, the kWh output of Orion's generating plant is less than Orion's
kWh load, the applicable general service rate elhall apply to that portion of demand and energy
exceeding the output, except during one month each calendar year which is mutually agreed
upon by SPS and Orion wherein scheduled boiler inspection and maintenance is conducted.
During that month, all kWh will be billed at the above contract rate.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If
the sixteenth day falls on a holiday or weekend, the due date will be the next work day.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Applicable Primary General Service Demand charge x
((0.95 customer's power factor xkW demand) — kW demand)
FUEL COST RECOVERY: The net charge per kWh delivered under the above contract rate shall be
increased by the primary distribution fuel cost recovery factor provided in PUCT Sheet No. IV -
69.
ORIGINAL CONTRACT PERIOD: January 1,1989 — December 31,1995.
ANNUAL MINIMUM CHARGE: The contract rate for an amount of kWh calculated by multiplying
the maximum kW demand of Orion's load experienced during the prior twelve months by 5,256
hours. ^
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000061
XcelEnei'igym
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 25 of 75
67
Section No. IV
Sheet No. IV -108
Revision No. 12 T
Page 1 of 4
LARGE GENERAL SERVICE - TRANSNIISSION
APPLICABILITY: Under contract to all commercial and industrial electric service supplied at
transmission level voltage at one Point of Delivery and measured throu__ one meter, where
facilities of adequate capacity and suitable voltage of 69 kV or higher is adjacent to the premises
to be served.
Not applicable to standby, supplementary, resale or shared service.
TERRITORY: Texas service territory.
OUTSIDE CITY LIMITS
SUB TRANSMISSION SERVICE OF 69 KV:
RATE: Service Availability Charge Per Month: $710.00
Energy Charge: $0.004505 per kWh for all kWh used during the month
Demand. Charge: $11.68 per kW of demand used per month during each summer month
$ 8.13 per kW of demand used per month during each winter month
TRANSMISSION SERVICE OF 115 KV AND ABOVE:
RATE: Service Availability Charge Per Month: $710.00
Energy Charge: $0.004273 per kWh for all kWh used during the month
Demand Charge: $11.16 per kW of demand used per month during each summer month
$ 7.81 per kW of demand used per month during each winter month
INSIDE CITY LIMITS
SUB TRANSMISSION SERVICE OF 69 KV:
RATE: Service Availability Charge Per Month: $710.00
Energy Charge: $0.005798 per kWh for all kWh used during the month
Demand Charge: $11.68 per kW of demand used per month during each summer month
$ 8.13 per kW of demand used per month during each winter month
I
I
I
I
I
I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000062
68
XcelEnergym
SOUTHWESTERN Pante SERVICE
ELECTRIC TARIFF
Attachment B
Page 26 of 75
Section No. 11/
Sheet No. IV -108
Revision No. 12 T
Page 2 of 4
LARGE GENERAL SERVICE - TRANSMISSION
TRANSMISSION SERVICE OF 115 KV AND ABOVE:
RATE: Service Availability Charge Per Month: $710.00
Energy Charge: $0.005566 per kWh for all kWh used during the month
Demand Charge: $11.16 per kW of demand used per month during each summer month
$ 7.81 per kW of demand used per month during each winter month
APPLICABLE TO BOTH INSIDE AND OUTSIDE CITY LIMITS
SUMMER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October — May.
OPTIONAL SERVICE: Customers receiving service under this rate may elect to receive interruptible
service by participating in the Interruptible Credit Option.
DETERMINATION OF DEMAND: The kW determined from Company's demand meter for the 30 -
minute period of Customer's greatest kW use during the month, but not less than 70 percent of
the highest demand established in the preceding eleven months.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 ± customer's power factor x kW
demand) — kW demand)
LOSS ADJUSTMENT: Meter readings used for billing shall be increased to include transformation
losses when a meter is installed on the secondary side of any voltage transformation under 69 kV
made on Customer's side of the point of service.
k'ULL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjustments.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000063
Xce Energy-
.&OUTNWaSTERN Paatre &Mitt
ELECTRIC TARIFF
Attachment B
Page 27 of 75
Section No. IV
Sheet No. IV -108
Revision No. 12 T
Page 3 of 4
LARGE GENERAL SERVICE - TRANSMISSION
CHARACTER OF SERVICE: Three phase, 60 hertz, supplied to the entire premises at approximately
69 kV or above.
LINE EXTENSIONS: All cost of equipment, supplies, and labor related to the installation of facilities
necessary to make service available shall be paid by Customer in advance. No transformation
will be made by Company at the point of service unless agreed to by Company.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill anter 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF S1 atVICE: Service supplied pursuant to this
schedule is subject to the terms and conditions set forth in the Company's Rules, Regulations and
Conditions of Service on file with the Public Utility Commission of Texas and to the terms and
conditions of any special contract service between Company and Customer that are not in
conflict herewith.
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA
§39.904(m-1) and Commission regulations promulgated thereunder, shall receive a credit of
$0.000191 per kWh to their electric billings. Customers who receive REC credits under this tariff
do not share in any REC costs and shall not be eligible to receive revenue credits for sales of
RECs by the Company.
115 kV Customers who provide written notice to the Comxws.Qion pursuant to PURA §39.904(m-
1) and Commission regulations promulgated thereunder, shall receive a credit of $0.000190 per
kWh to their electric billings. Customers who receive REC credits under this tariff do not share
in any REC costs and shall not be eligible to receive revenue credits for sales of RECs by
Company.
SUBSTATION LEASE: Company reserves the option to lease substation facilities. If the substation
facilities to be leased serve a single Customer, that Customer must lease 100% of the facilities. If
the substation facilities to be leased serve multiple Customers, Company will determine a
percentage of the substation capacity to be leased to the lessee, but no less than 4000 RVA of
substation capacity will be leased to a single Customer. The monthly lease charge will be two
percent of the net reproduction costs of the leased facilities, calculated as of the commencement
of the lease, and shall be paid by Customer to Company along with the monthly invoice for
REGIONAL VICE PRES1DE1 T RATES AND
REGULATORY AFFMBSI
000064
69
70
XceIEnergr
SOUTNWEStERN PUB[rC SERVICE
ELECTRIC TARIFF
Attachment B
Page 28 of 75
Section No. IV
Sheet No. IV -108
Revision No. 12
Page 4 of 4
T
LARGE GENERAL SERVICE - TRANSMISSION
SUBSTATION LEASE (cont.):
electric service. Company reserves the right to increase the monthly substation lease charge
whenever Company spends more than $100,000 in repairs, replacements, or upgrades to the
Leased substation facilities in any consecutive twelve month period during the term of the lease.
The minimum lease term shall be 120 months and shall continue month to month thereafter unti
the lease agreement is terminated. The lease agreement may be terminated by Customer with at
least six months prior written notice to Company. If Customer terminates the lease without
giving Company six months prior written notice or (2) earlier than 120 months from the
commencement of the lease, the following termination penalty shall apply:
Customer shall pay a lease termination penalty of the net present value, using a rate of 8.12 R
percent applied to the sum calculated as follows:
1. If Customer has made 120 or more monthly lease payments, the sum shall be six times the
monthly lease payment.
2. If Customer has made less than 120 monthly lease payments, the sum will be 120, less the
number of monthly lease payments made (but no less than six), times the monthly lease payment.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000065
"0,
lEnergy'
SiUfBWF&lPXli PUBLIC &Mitt
ELECTRIC TARIFF
Attachment B
Page 29 of 75
71
Section No. IV
Sheet No. W-109
Revision No. 13
Page 1 of 2
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: WRB Refining L.P.
POINTS OF SERVICE: WRB Refining L.P. Refinery and Chemical
Complex near Borger, Texas.
APPLICABILITY: Transmission service at or above 69 kV.
RATE: Service Availability Charge Per Month: $710.00
Energy Charge:
$0.004505 per kWh for all kWh used during the month
Demand Charge:
$11.68 per kW of demand used per month during each summer month
$ 8.13 per kW of demand used per month during each winter month
SIMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
OPTIONAL SERVICE: Customers receiving service under this rats niay elect to receive interruptible
service under the Interruptible Credit Option.
NOTE: All meter readings of service under this tariff at common voltage levels will be combined for
billing purposes.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If
the sixteenth day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF DEMAND: The kW determined from the Company's demand meters for the
30 -minute period of Customer's greatest kW use dining the month, but not less than 70 percent
of the highest demand established in the preceding eleven months.
I
I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000066
72
Xcel Energr
SOUT11W1ST1ERN PU*LIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 30 of 75
Section No. W
Sheet No. IV -109
Revision No. 13 T
Page 2of2
SERVICE AGREEMENT SUMMARY
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA
§39.904(m-1) and Commission regulations promulgated thereunder, shall receive a credit of
$0.000191 per kWh to their electric billings. Customers who receive RBC credits under this tariff I
do not share in any RBC costs and shall not be eligible to receive revenue credits for sales of
RECs by the Company.
LOSS ADJUSTMENT: Meter readings used for billing cha11 be increased to include transformation
losses when metering is installed on the secondary side of any voltage transformation under 69
kV made on Customer's side of the Point of Delivery.
LINE EXTENSIONS: All cost of equipment, supplies, and labor related to the installation cost of
facilities necessary to make service available shall be paid by the Customer in advance. No
transformation will be made by the Company at the point of service.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon: -
Power Factor Adjustment Charge = Demand charge x ((0.95 customer's power factor x kW
demand) - kW demand)
CRARACTER OF SERVICE: A -C; 60 hertz; at one available standard transmission voltage for each
point of service.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the
applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
.‘„„00
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000067
XcelEnergy
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 31 of 75
73
Section No. IV
Sheet No. IV -118
Revision No. 10 T
Page 1 of 3
FLOOD LIGHT SERVICE
APPLICABLILITY:
Under contract to all night outdoor flood light service, where facilities of adequate capacity and
suitable voltage are adjacent to the premises to be served. This tariff will be closed to new
Customers as of September 1, 2000 in accordance with the Public Utility Commission of Texas
Order in Docket No. 21190, and no new lights will be installed. If this service is in effect at a
property that is sold to a new Customer, the new Customer may continue this service at that
property if the new Customer agrees to the rate then in effect for this service.
TERRITORY: Texas service territory.
RATE: The charge per month shall be the sum of A + B + C.
A. Charge per lamp, per month, for the first light on each 30 -foot wood pole with overhead service:
Lamp Wattage Metal Halide High Pressure Sodium
150 N/A $19.20 R
175 $19.32 NIA R
250 $20.70 $20.80 R
400 $21.53 $22.01 R
1,000 $32.95 $33.36 R
B. Added charge per month for each additional lamp per pole:
Lamp Wattage Metal Halide Hiuh Pressure Sodium
150 N/A $6.03 R
175 $6.11 N/A R
250 6.97 7.04 R
400 7.55 7.87 R
1,000 15.77 16.02 R
C. Additional charge per month, per pole:
Added Charge Added Charge Added Charge
Pole Per Overhead Per Wood Pole Added Charge Per Steel Pole
Height Wood Pole Underground Per Steel Pole Undersround
30' $ .00 $2.42 $4.03 $6.46
35' 1.19 3.61 5.24 7.65
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000068
74
XcelEnergr
SOUYHWS'StERN PUBLIC selv1c8
ELECTRIC TARIFF
Attachment B
Page 32 of 75
Section No. W
Sheet No. IV -118
Revision No. 10 T
Page 2 of 3
FLOOD LIGHT SERVICE
Added Charge Added Charge Added Charge
Pole Per Overhead Per Wood Pole Added Charge Per Steel Pole
Aei¢ht Wood Pole Underground Per Steel Pole Underground
40' 2.54 4.97 6.59 9.01
45' 3.60 6.04 7.64 10.07
50' 4.77 7.19 N/A N/A
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF ENERGY USE:
Lamp Metal Halide High Pressure. Sodium
Wattaue Lumen kWh Lumen kWh
150 15,000 56
175 14,000 62 --
250 20,500 97 27,500 97
400 36,000 136 50,000 159
1,000 110,000 359 140,000 350
FUEL COST RECOVERY:
The above rate shall be increased by the applicable fuel cost recovery factor per kWh, provided in
PUCT Sheet No. IV -69. However, Flood Light Systems service provided by the Company which
is connected to a circuit previously metered by Company for other electric service, shall not have
the above rate increased by the applicable fuel cost recovery factor.
CONDITIONS OF SERVICE:
Company will construct, own, operate and maintain, on the Customer's premises, the required
number of photo -electrically controlled overhead flood lights of the type and size selected by
Customer, installed on Company's poles, and having a secondary line span less than 150 feet in
length.
Company will not construct, own or maintain underground lines on Customer's premises.
Construction of underground lines will be to the specifications of Company, and will be arranged
and paid for by the Customer. Customer is responsible for any trenching and backfilling
necessary for construction.
R
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000069
XceIEnergy
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 33 of 75
75
Section No. N
Sheet No. IV -118
Revision No. 10 T
Page3 of3
FLOOD LIGHT SERVICE
CHARACTER OF SERVICE: A C; 60 hertz; single phase; 120 or 240 volts.
TERM OF CONTRACT: A period of not less than three years.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations, and
Conditions of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000070
76
XclEnergy
souriwsarEBN PUsLEC &eaMICE
ELECTRIC TARIFF
Attachment B
Page 34 of 75
Section No. IV
Sheet No. IV -144
Revision No. 3 T
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Under contract to City of Amarillo, Texas for highway sign lighting.
TERRITORY: Amarillo, Texas.
RATE: $0.032401 per kWh.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet No. IV -69.
MINIMUM CHARGE: $4.00 per meter for single phase service; $10.00 per meter for three phase
service.
LINE EXTENSIONS: The Company will make line extensions in accordance with its standard line
extension policy.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000071
XcelEnergy '
SOUTHWESTERN Pint1C SEkVICE
77
ELECTRIC TARIFF
Attachment B
Page 35 of 75
Section No. IV
Sheet No. IV -150
Revision No. 9 T
Pagel of 3
RESTRICTED OUTDOOR LIGHTING SERVICE
APPLICABILITY: Under contract for night outdoor lighting service where facilities of adequate
capacity and suitable voltage are available and service is being provided at the time of the
Company's acquisition of Texas New Mexico Power Company's property in Hansford, Ochiltree
and Lipscomb Counties
Pursuant to the 2005 Energy Policy Act, mercury vapor (MV) lamp ballasts shall not be
manufactured or imported after January 1, 2008. When the Company's inventory of mercury
vapor ballasts and lamps is exhausted, Customers will be given the option of having the lighting
facilities removed, or replaced with another type of light at the rate for the replacement light.
TERMS OF SERVICE: No new Customers will be added to this service; however, if this service is
• provided to a privately -owned property and the property is sold to a new Customer, the new
Customer has the option to continue service under the existing rate if the new Customer agrees to
the rate then in effect for this service. Existing equipment will be replaced with standard
Company equipment as wear -out and obsolescence occur, if the Customer agrees to continue
service under the rate then in effect for standard Company equipment.
TERRITORY: Areas in the counties of Hansford, Ochiltree, and Lipscomb previously served by Texas-
• New Mexico Power Company.
GUARD LlukrfS:
RATE: Each 21,500 lumen, 400 watt, mercury vapor lamp for $16.24 per month.
Each 9,500 lumen, 100 watt, high pressure sodium (HPS) lamp for $12.41 per month.
Each 22,000 lumen, 200 watt, BPS lamp for $13.68 per month.
FLOOD LIGHTS:
RATE: Each 21,500 lumen, 400 watt, MV lamp for $1624 per month.
Each 36,000 lumen, 400 watt; metal halide (MH) lamp for $21.53 per month.
Bach 110,000 lumen, 1,000 watt, MH lamp for $32.95 per month.
Each 50,000 lumen, 400 watt, HPS lamp for $22.01 per month.
Company will own, operate and maintain on Customer's premises, the number of photo-
electrically controlled lamps requested by Customer, mounted on a metal bracket, installed on
Company's service pole, a separate 30 foot pole or on any suitable mounting device belonging to
R
R
R
R
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000072
1
78
XcelEnergysx
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 36 of 75
Section No. IV
Sheet No. W-150
Revision No. 9 T
Page 2 of 3
RESTRICTED OUTDOOR LIGATING SERVICE
RATE (Cont):
Customer, and having a secondary line span not to exceed 150 feet in length. Lights will not be
installed on any mounting device which, in the opinion of Company, is unsafe or unsuitable for
this purpose.
The charge per lamp, per month shall be in accordance with the following rates:
Lumen Lamp Wood 8tdergreund Ornamental
Lamp Type Pole Fele
Size
8,150 MV $
9,500 EPS $10.81 $ $
22,000 HE'S $11.91 $ $
The aforementioned rates include furnishing, by Company, of the electric energy necessary to
operate the street lighting system, the replacement of lamps and normal maintenance of fixtures,
wires, transfonners and other component parts of the street lighting system, as said replacements
and maintenance become necessary. In the event maintenance and/or lamp and glassware
replacements become excessive due to vandalism or similar causes, Company will notify the
City, and the City will implement whatever means at its disposal through law enforcement
agencies or other protective measures, to eliminate destruction of street lighting equipment If
said vandalism persists, Company reserves the right to remove the street lights.
If any street light is permanently removed from service at the City's request; the City will pay
Company, at the time of removal from service of said light, the original cost of the equipment
taken out of service, less depreciation of four percent per year. If any street light is removed from
service temporarily (at least two months) at the City's request, the monthly rate for said light
during such temporary disconnection will be the base charge per lamp as stated above. Fuel cost
recovery will not be charged or credited on any temporarily disconnected street light
Company will install, own, operate and maintain the street lighting system. If, for any reason,
Culupany is unable to continue service of particular equipment, said equipment, at the option of
the City, will be removed or replaced by Company with currently available equipment, and the
City will pay the appropriate rate for the new equipment.
D
D
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000073
1(Ir Xce Energr
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 37 of 75
79
Section No. IV
Sheet No. IV -150
Revision No. 9 T
Page 3 of 3
RESTRICTED OUTDOOR LIGHTING SERVICE
RATE (Cont.):
Street light burning time will be from approximately one-ba1f hour after sunset to approximately
one-half hour before sunrise.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If
service is billed on a residential bill, the late payment charge will not be imposed. If the sixteenth
day falls on a holiday or weekend, the due date will be the following work day.
DETERMINATION OF ENERGY USE:
8,150 lumen, 175 watt,
21,500 lumen, 400 watt,
9,500 lumen, 100 watt,
22,000 lumen, 200 watt,
34,000lumen, 400 watt,
110,000 lumen, 1,000 watt,
25,500 lumen, 250 watt,
50,000 lumen, 400 watt,
MV lamp uses 68 kWh per month
MV lamp uses 151 kWh per month
HPS lamp uses 39 kWh per month
HPS lamp uses 75 kWh per month
MH lamp uses 136 kWh per month
MH lamp uses 359 kWh per month
HPS lamp uses 97 kWh per month
HPS lamp uses 159 kWh per month
FUEL COST RECOVERY: The charge per kWh of the aforementioned rate shall be increased by the
applicable fuel cost factor per kWh as provided in PUCT Sheet IV -69. However, Outdoor
Lighting Service provided by Company, which is connected to a circuit previously metered by
Company for other electric service, shall not have the above rate increased by the applicable fuel
cost recovery factor.
CHARM -UR UR OF SERVICE: A -C; 60 hertz; single phase; 120 or 240 volts.
RULES, REGULATIONS AND CONDITIONS 01? SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in Company's Rules, Regulations, and Conditions
of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000074
80
XcelEnergyv
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 38 of 75
Section No. IV
Sheet No. IV -172
Revision No. 8 T
Page 1 of 3
SMALL GENERAL SERVICE
APPLICABILITY: To commercial Customers for electric service used at secondary voltage and used
for commercial purposes when all service is supplied at one Point of Delivery, and measured
through one meter, where facilities of adequate capacity and suitable voltage are adjacent to the
premises to be served, not to exceed 10 kW of demand in any month. Single phase motors not to
exceed 10 horsepower, individual capacity, may be served under this rate.
Each year, Company will review the demand of all Customers receiving service under this tariff
for whom Company has installed the necessary equipment to measure Customer's kW demand.
If the average of Customer's twelve monthly demands in the immediately preceding calendar
year exceeds 10 kW, then Customer is not eligible to continue receiving service under this tariff.
Not applicable to standby, supplementary, resale, or shared service, or service to oil and natural
gas production facilities.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $11.25 per month. R
Energy Charge: $0.063138 per kWh for all kWh used per month during each summer month I
$0.053482 per kWh for all kWh used per month during each winter month. I
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
ALTERNATE EXPERIMENTAL TIME OF USE RIDER
RATE: Service Availability Charge: $12.25 per month. R
Energy Charge:
$0.045384 per kWh fok all kWh used during all hours, PLUS I
$0.137365 per kWh for all kWh used during On -Peak Hours I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000075
/0",
Xf Energy
SOUTHWESTERN POMO SERVICE
EL 1 CTRIC TARIFF
81
Attachment B
Page 39 of 75
Section No. IV
Sheet No. IV -172
Revision No. 8
Page 2 of 3
SMALL GENERAL SERVICE
ON -PEAK HOURS: 1 pin. through 7 p.m., Monday through Friday during the months of June through
September.
Availability limited to a maximum of 50 customers that qualify for service under Small General
Service. Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June through September. The Off -Peak period shall be all other hours
not covered in the On -Peak period.
DEMAND: If, over any four consecutive months, a Customer's average monthly usage exceeds 3,500
kWh, Company will furnish, at Company's expense, the necessary equipment to measure
Customer's kW demand for the 30 -minute period of greatest use during the month.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate aha11 be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjustments.
AVERAGE MONTHLY PAYMENT: Upon request, any commercial Customer may be billed
monthly based on a levelized payment plan. A Customer's monthly payment amount is
calculated by obtaining the most recent twelve months of actual consumption and dividing that
amount by twelve, and applying the Company's current rates to the average kWh consumption.
The account will be trued up every twelve months. The trued -up amount will be equal to the
difference between the total of the prior twelve months' levelized payments and the actual
billings for the corresponding most recent twelve month period.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase 120/240 volts; or where available
secondary, three phase 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after sixteen days.
If the sixteenth day falls on. a holiday or weekend, the due date will be the next work day.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000076
82
XcelEnergr
SOUINIV SrENN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 40 of 75
Section No. IV
Sheet No. IV -172
Revision No. 8 T
Page 3 of 3
SMALL GENERAL SERVICE
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations and
Conditions of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000077
XcelEnergy"
SOUTHWESTERN PUBtfC SERVICE
ELECTRIC TARIFF
Attachment B
Page 41 of 75
83
Section No. IV
Sheet No. IV -173
Revision No. 9 T
Page l of 2
PRIMARY GENERAL SERVICE
APPLICABILITY: To all commercial and industrial electric service supplied at a primary voltage of
2.4kV or higher but less than 69 kV and at a single Point of Delivery measured through approved
electrical metering determined by Company, where facilities of adequate capacity and suitable
voltage are adjacent to the premises to be served.
Not applicable to standby, supplementary, resale or shared service.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $58.50 per month
Energy Charge: $0.005960 per kWh for all kWh used during the month R
Demand Charge: $12.76 per kW of demand used per month during each summer month
$10.98 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
DETERMINATION OF DEMAND: The kW determined from Company's demand meter for the
30 -minute period of Customer's greatest kW use during the month.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered thirty -
minute kW demand interval is Less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 = customer's power factor x kW
demand) — kW demand).
LOSS ADJUSTMENT: Meter readings used for billing shall be increased to include line and
transformation losses when Customer's load is Metered at a secondary voltage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000078
84
0." XCeI Energy
SOUTNWESTEEM "USW SERVICE
ELECTRIC TARIFF
Attachment B
Page 42 of 75
Section No. IV
Sheet No. IV -173
Revision No. 9 T
Page 2 of 2
PRIMARY GENERAL SERVICE
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate aha11 be
increased by the applicable feel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjusbnents
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase at Company's available primary
voltage that is 2.4 kV or higher but less than 69 kV.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy, and no transformation will be made by Company at the Point of Delivery.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations, and
Conditions of Service on file with the Public Utility Commission of Texas. Company may
require a Contract to be executed prior to extending service if Customer's load is expected to be
greater than 200 kW. The contract term shall contain a minimum contract period with an
automatic renewable provision from year to year thereafter.
„0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000079
t"), XCelEnergr
£OUTNWISTEXN Puatic sfkVitt
ELECTRIC TARIFF
85
Attachment B
Page 43 of 75
Section No. IV
Sheet No, IV -174
Revision No. 8
Page 1 of 2
SMALL MUNICIPAL AND SCHOOL SERVICE
APPLICABILITY: To Municipal facilities and K-12 schools both public and private for
electric service used at secondary voltage and used for municipal and school purposes
when all service is supplied at one point of delivery, and measured through one meter,
where facilities of adequate capacity and suitable voltage are adjacent to the premises to
be served, not to exceed 10 kW of demand in any month. Single phase motors not to
exceed 10 horsepower, individual capacity, may be served under this rate.
Each year, Company will review the demand of all Customers receiving service under
this tariff for whom Company has installed the necessary equipment to measure
Customer's kW demand. If the average of Customer's twelve monthly demands in the
immediately preceding calendar year exceeds 10 kW, then Customer is not eligible to
continue receiving service under this tariff.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $13.20 per month.
Energy Charge:
$0.045136 per kWh for all kWh used per month during each summer month:
$0.038897 per kWh for all kWh used per month during each winter month.
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
ALTERNATE EXPERIMENTAL TIME OF USE RIDER
RATE: Service Availability Charge: $1420 per month.
Energy Charge:
$0.033458 per kWh for all kWh used during all hours, PLUS
$0.117987 per kWh for all kWh used during On -Peak Hours
I
R
R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000080
86
X+e1 Energy-
SOU?H'WBSTFRN PUBLIC SEIVICE
ELECTRIC TARIFF
Attachment B
Page 44 of 75
Section No. TV
Sheet No. IV -174•
Revision No. 8 T
Page 2 of 2
SMALL MUNICIPAL AND SCHOOL SERVICE
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months offline through
September.
Availability limited to a maximum of 50 customers that qualify for service under Small Municipal
and School Service. Customers must contract for service under this experimental tariff for a
minimum of 12 consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm,
Monday through Friday during the months of June through September. The Off -Peak period shall
be all other hours not covered in the On -Peak period.
DEMAND: If, over any four consecutive months, a Customer's average monthly usage exceeds 3,500
kWh, Company will furnish, at Company's expense, the necessary equipment to measure
Customer's kW demand for the 30 -minute period of greatest use during the month.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjustments as in effect from time to time in
this tariff.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard
secondary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date: 5 percent added to bill after sixteen days. If
the sixteenth day falls on a holiday or weekend, the due date will be lho next work day.
RULES, REGULATIONS, AND CONDITIONS OF SERVICE:
Service supplied under this schedule is subject to the terms and conditions set forth in
Company's Rules and Regulations on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORYAFFAIRS
000081
re?,
X iEner
SOUTHWEb7FRN PUHfC SttV10E
ELECTRIC TARIFF
Attachment B
Page 45 of 75
87
Section No. IV
Sheet No. IV -175
Revision No. 9 T
Page 1 of 3
LARGE MUNICIPAL SERVICE
APPLICABILITY: To all municipal facilities supplied electric service at primary or secondary voltage,
at a single point of delivery measured through one meter, where facilities of adequate capacity
and suitable voltage are adjacent to the premises to be served, exceeding 10 kW of demand in any
month.
Each year, Company will review the demand of all Customers receiving service under this tariff.
If the average of Customer's twelve monthly demands in the immediately preceding calendar
year does not exceed 10 kW, then Customer is not eligible to continue receiving service under
this tariff.
Not applicable to supplementary or shared service, or to service for which a specific rate schedule
is provided.
TERRITORY: Texas service territory.
SECONDARY VOLTAGE:
RATE: Service Availability Charge: $25.90 per month
Energy Charge: $0.007692 per kWh for all kWh used during the month
Demand Charge: $10.87 per kW of demand used per month during each summer month
$ 8.90 per kW of demand used per month during each winter month
PRIMARY VOLTAGE:
RATE: Service Availability Charge: $25.90 per month
Energy Charge: $0.007573 per kWh for all kWh used during the month
Demand Charge: $10.73 per kW of demand used per month during each summer month
$ &.80 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000082
88
XceiEnerg
SOITHWISTE1NN PUBLIC usxv:ci
ELECTRIC TARIFF
Attachment B
Page 46 of 75
Section No. IV
Sheet No. IV -175
Revision No. 9 T
Page 2 of 3
LARGE MUNICIPAL SERVICE
ALTERNATE EXPERIMENTAL TIME OF USE RIDER — SECONDARY VOLTAGE
RATE: Service Availability Charge: $26.90 per month.
Energy Charge:
$0.007692 per kWh for all kWh used during all hours, PLUS
$0.122527 per kWh for all kWh used during On -Peak Hours
Demand Charge: $7.30 per kW of demand used per month
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June through
September.
ALTERNATE EXPEREVIENTAL TIME OF USE RIDER — PRIMARY VOLTAGE
RATE: Service Availability Charge: $26.90 per month.
Energy Charge:
$0.007573 per kWh for all kWh used during all hours, PLUS
$0.120055 per kWh for all kWh used during On -Peak Hours
Demand Charge: $7.34 per kW of demand used per month
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June through
September.
Availability limited to a maximum of 50 customers that qualify for service under Large Municipal
Service, secondary and primary voltage combined. Customers must contract for service under this
experimental tariff for a minimum of 12 consecutive calendar months. The On -Peak period shall be
1:00 pm to 7:00 pm, Monday through Friday during the months of June through September. The
Off -Peak period shall be all other hours not covered in the On -Peak period.
DEMAND: Company will furnish, at its expense, the necessary metering equipment to measure
Customer's kW demand for the 30 -minute period of greatest use during the month. In no month
shall the billing demand be greater than the value in kW determined by dividing the kWh sales for
the billing period by 80 hours.
I
I
I
I
I
I
I
I
�a-
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000083
XC Enrg
SOUTHWESTERN PUILUC SEEV10E
ELECTRIC TARIFF
Attachment B
Page 47 of 75
89
Section No. IV
Sheet No. IV -175
Revision No. 9 T
Page 3 of 3
LARGE MUNICIPAL SERVICE
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand exceeding 200 kW. A Power Factor Adjustment will apply to all customers with power
factor metering if the power factor at the time of the highest metered thirty minute kW demand
interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 - customer's power factor x kW
demand)- kW demand)
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard
secondary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in Company's Rules, Regulations and Conditions
of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000084
90
XCeiEnergr
SOUTHWESTERN POSLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 48 of 75
Section No. W
Sheet No. W-179
Revision No. 8 T
Page 1 of 4
PRIMARY QF STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at a primary voltage of 2.4 kV or higher
but less than 69 kV and supplied at one Point of Delivery, for which Company's service is used
as standby, backup or maintenance service. Applies to Customers who operate any electric
generating equipment in parallel with Company's electric system which normally serves all or a
portion of the Customer's electrical load requirements; who requires Standby Capacity from ihe
Company; and who desire use of the Company's electrical service for temporary backup or
maintenance power and energy. Not applicable to power generated for resale.
AVAILABILITY: Service hereunder is available only to Customers who have executed an Electric
Service Agreement with the Company that specifies Customer's Contract Standby Capacity and
Total Load requirements. All power service supplied by Company to Customer in excess of the
contract Standby Capacity shall be provided by Company under the Primary General Service
("PG") tari$ Standby service provided for Customer generation hereunder is not available under
the Company's Interruptible Credit Option ("ICO") tariff. Customers receiving service under this
tariff shall be billed on a calendar month basis, such that the first day of each month shall be the
beginning and the last day of each month shall be the end of the monthly billing period.
RATE: Service Availability Charge:
Transmission & Distribution Standby Capacity Fee — Summer:
Transmission & Distribution Standby Capacity Fee — Winter:
Generation Standby Capacity Fee — Summer:
Generation Standby Capacity Fee — Winter:
Energy Charge: for all kWh used during the month
EXCESS USAGE.
If Customer Usage Hours exceed 99 Usage Hours, the above
charges shall not apply and the charges will be as follows:
$58.50 per month
$7.05 / kW Month
$6.32 / kW Month
$1.45 /kW Month
$1.19 /kW Month
$0.005960 per kWh
Service Availability Charge: $58.50 per month
Usage Demand Charge - Summer:
Usage Demand Charge - Winter.
$12.76 / kW Month
$10.98 /kW Month
I
I
I
R
I
R
I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000085
XcelEnergya
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 49 of 75
Section No. IV
Sheet No. N-179
Revision No. 8 T
Page2of4
PRIMARY QF STANDBY SERVICE
Energy Charge: for all kWh used during the month $0.005960 per kWh R
SUMMER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October — May.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered thirty -
minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 - customer's power factor x kW
demand) — kW demand)
DEFINITIONS:
CONTRACT STANDBY CAPACITY: The level of Contract Standby Capacity in kilowatts the
Company reserves in its transmission and distribution systems and its generation for the
Customer as set forth in the Electric Standby Service Agreement. Contract Standby Capacity is
limited to and is the lesser of
■ the Customer's Total Load,
■ the Customer's generation capacity, or
■ an amount agreed to by the Company and the Customer.
CUSTOMER'S TOTAL LOAD: Represents the maximum historical level of electrical demand at the
Customer's service location on or after January 1', 2012, and shall be determined by meter
measurement of the total capacity requirements of Customer, regardless of whether such capacity
is supplied by Company, Customer's own generation equipment, or a combination of both.
Customer's Total Load shall carry forward from year-to-year until Customer's maximum demand
CUSTOMER'S TOTAL LOAD (cont.):
exceeds previous Total Load. In the month following the month in which larger total was
metered, the larger value would then become the Customer's Total Load.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000086
91
92
XceIEnergy
SOUtilVISMXN 'Owe S@1v10E
FLFCTRIC TARIFF
Attachment B
Page 50 of 75
Section No. IV
Sheet No. IV -179
Revision No. 8
Page 3 of 4
PRIMARY QF STANDBY SERVICE
STANDBY SERVICE: Standby Service shall be the service provided by Company under this Primary
Standby Service tariff.
USAGE HOURS: Each hour in a calendar month during which a 30 -minute interval of Customer
generation is less than the lower of Customer Usage or 60% of Contract Standby Capacity,
excluding energy used during Qualified Scheduled Maintenance Periods, is considered a Usage
Hour. If the number of Usage Hours in a month is 100 or more hours, Customer shall pay
according to the provisions of Excess Usage for Standby Service.
CONTRACT PERIOD: All contracts under this schedule shall be for a minimum period of one year
and one-year periods thereafter until terminated, where service is no longer required, on 30 days
notice. Greater minimum periods may be required by contract in situations involving large or
unusual loads.
METER INSTALLATION: Company shall install, own, operate, and maintain the metering to measure
the electric power and energy supplied to Customer to allow for proper billing of the separate PG
Service and Standby Service demands and grace period identified above. In particular, Company
will install a meter that measures the flow of power and energy from Customer's own generating
facility (generation metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company
may determine that it is more practical or economical to use generation metering installed and
owned by Customer, rather than Company-owned metering equipment. If Company, at its sole
discretion, makes such a determination, then Customer -owned generation metering may be used
for the billing purposes, so long as such metering equipment meets Company's standards for
quality and accuracy.
If through the course of Company's evaluation of the metering requirements for the generation
meter(s), Company determines, at its sole discretion, that it is impracticable, uneconomical or
unnecessary to install metering on Customer's generator(s), Company shall determine the billing
for the provision of the Standby Service tariff on an un -metered and calculated basis. This
determination can only be made if the only electrical load located at Customer's site is station
power equipment as defined by the Federal Energy Regulatory Commission.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000087
XcelEnergr
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 51 of 75
Section No. IV
Sheet No. IV -179
Revision No. 8 T
Page 4 of 4
PRIMARY QF STANDBY SERVICE
METER INSTALLATION (cont.):
Regardless of Company's ultimate determination of the requirement (or lack thereof) for
installation of the generation metering, a meter will always be required at the point of
interconnection between Company and Customer and such meter will measure both delivered and
received capacity and energy.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE; Qualifying Scheduled Maintenance Periods must occur within the winter
months as defined above. Customer must provide Company with 30 days written notice of
scheduled maintenance prior to the beginning of the maintenance period. The duration of
qualifying scheduled maintenance periods may not exceed a total of six weeks in any 12 -month
period
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods
shall result in the energy used during unapproved maintenance outages being applied against the
Usage Hours energy limit
DEFINITION OF SUPPLEMENTAL DEMAND: If Customer's Total Load is in excess of the
Contract Standby Demand, the Supplemental Demand (kW) is equal to Customer's Total Load
minus the Contract Standby Capacity. Supplemental Demand and energy will be billed on the
applicable PG tariff.
FUEL COST RECOVERY: The charge per kWh of the above rate shrill be increased by the applicable
fuel cost recovery per kWh as provided in PUCT Sheet No. IV -69.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE: A -C 60 hertz, single or three phase at Company's available primary
voltage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000088
93
94
'* Xcel Energy-
SDUTNWUSMIN PUBLIC SBRVWCt
ELECTRIC TARIFF
Attachment B
Page 52 of 75
Section No. IV
Sheet No. IV -180
Revision No. 8 T
Page 1 of 4
SECONDARY QF STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at secondary voltage supplied at one
Point of Delivery, for which Company's service is used as standby backup or maintenance
service. Applies to Customers who operate any electric generating equipment in parallel with
Company's electric system which normally serves all or a portion of Customer's electrical load
requirements; who requires Standby Capacity from Company, and who desire use of Company's
electrical service for temporary backup or maintenance power and energy. Not applicable to
power generated for resale.
AVAILABILITY:
Service hereunder is available only to Customers who have executed an Electric Service
Agreement with Company that specifies Customer's Contract Standby Capacity and Total Load
requirements. All power service supplied by Company to the Customer in excess of the contract
Standby Capacity shall be provided by Company under the Secondary General Service ("SG")
tariff. Service hereunder is not available under Company's Interruptible Credit Option ("ICO")
tariff Customers receiving service under this tariff shall be billed on a calendar month basis,
such that the first day of each month shall be the beginning and the last day of each month shall
be the end of the monthly billing period.
RATE: Service Availability Charge:
Transmission & Distribution Standby Capacity Fee - Summer.
Transmission & Distribution Standby Capacity Fee — Winter
Generation Standby Capacity Fee — Summer.
Generation Standby Capacity Fee — Wmter:
Energy Charge:
EXCESS USAGE
If Customer Usage Hours exceed 99 Usage Hours, the
above charges shall not apply and the charges will be as
follows:
Service Availability Charge:
Usage Demand Charge - Summer:
$25.60 per month
$8.24 /kW Month
$7.41 / kW Month
$1.72 / kW Month
$1.41 / kW Month
$0.007783 per kWh
$25.60 per month
$15.12/kW Month
R
I
I
I
I
I
R
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000089
xcelEne►gr
S0UrUWBSTERN PUBtrC $ERv1Ct
ELECTRIC TARIFF
Attachment 13
Page 53 of 75
95
Section No. IV
Sheet No. IV -180
Revision No. 8 T
Page 2 of 4
SECONDARY QF STANDBY SERVICE
Usage Demand Charge - Winter: $13.06 / kW Month
Energy Charge: for all kWh used during the month $0.007783 per kWh
SUMMER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October — May.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge Demand charge x ((0.95 = customer's power factor x kW
demand) — kW demand)
DEFINITIONS:
CONTRACT STANDBY CAPACITY:
The level of Contract Standby Capacity in kilowatts the Company reserves in its transmission and
distribution systems and its generation for the Customer as set forth in the Electric Standby
Service Agreement. The Contract Standby Capacity is limited to and is the lesser of:
• the Customer's Total Load,
■ the Customer's generation capacity, or
• an amount agreed to by the Company and the Customer.
CUSTOMER'S TOTAL LOAD:
Represents the maximum historical level of electrical demand at the Customer's service location
on or after January 1a, 2012, and shall be determined by meter measurement as the total capacity
requirements of Customer, regardless of whether such capacity is supplied by Company,
Customer's own generation equipment, or a combination of both. Customer's Total Load shall
carry forward from year-to-year until Customer's maximum demand exceeds previous Total
Load. In the month following the month in which larger total was metered, the larger value would
then become the Customer's Total Load.
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000090
96
XcelEnerfg r
SOUVHWiSTFKN PUBLIC $UVICE
ELECTRIC TARIFF
Attachment 13
Page 54 of 75
Section No. IV
Sheet No. IV -180
Revision No. 8 T
Page 3 of 4
SECONDARY QF STANDBY SERVICE
STANDBY SERVICE:
Standby Service shall be the service provided by Company under this Secondary Standby Service
tariff.
USAGE HOURS:
Each hour in a calendar month during which a 30 -minute interval of Customer generation is less
than the lower of Customer usage or 60% of Contract Standby Capacity, excluding energy used
during Qualified Scheduled Maintenance Periods, is considered a Usage Hour. If the number of
Usage Hours m a month is 100 or more hours, Customer shall pay according to the provisions of
Excess Usage for Standby Service.
CONTRACT PERIOD: All contracts under this schedule shall be for a minimum period of one year
and one-year periods thereafter until terminated, where service is no longer required, on 30 days
notice. Greater minimum periods may be required by contract in. situations involving large or
unusual loads.
METER INSTALLATION: Company shall install, own, operate, and maintain the metering to measure
the electric power and energy supplied to Customer to allow for proper billing of the separate SG
Service and Standby Service demands and grace period identified above. In particular, Company
will install a meter that measures the flow of power and energy from Customer's own generating
facility (generation metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company
may determine that it is more practical or economical to use generation metering installed and
owned by Customer, rather than Company-owned metering equipment If Company, at its sole
discretion, makes such a determination, then Customer -owned generation metering may be used
for the billing purposes, so long as such metering equipment meets Company's standards for
quality and accuracy.
If throngh the course of Company's evaluation of the metering requirements for the generation
meter(s), Company determines, at its sole discretion, that it is impracticable, uneconomical or
unnecessary to install metering on Customer's generator(s), Company shall determine the billing
for the provision of the Standby Service tariff on an um -metered and calculated basis. This
determination can only be made if the only electrical load located at Customer's site is station
power equipment as defined by the Federal Energy Regulatory Commission.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000091
XcelEnerg►yA
SBUTNWE lERN PUBLIC S£.£vJC£
ELECTRIC TARIFF
Attachment B
Page 55 of 75
97
Section No. IV
Sheet No. IV -180
Revision No. 8 T
Page 4 of 4
SECONDARY QF STANDBY SERVICE
METER INSTALLATION (cont.):
Regardless of Company's ultimate determination of the requirement (or lack thereof) for
installation of the generation metering, a meter will always be required at the point of
interconnection between Company and Customer and such meter will measure both delivered and
received capacity and energy.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE:
Qnmlifying Scheduled Maintenance Periods must occur within the winter months as defined
above. Customer must provide Company with 30 days written notice of scheduled maintenance
prior to the beginning of the maintenance period. The duration of qualifying scheduled
maintenance periods may not exceed a total of six weeks in any 12 -month period.
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods
shall result in the energy used during unapproved maintenance outages being applied agsinst the
Usage Hours energy limit.
DEFINIrION OF SUPPLEMENTAL DEMAND:
If Customer's Total Load is in excess of the Contract Standby Demand, the Supplemental
Demand (kW) is equal to Customer's Total Load minus the Contract Standby Capacity.
Supplemental Demand and energy will be billed on the applicable SG tariff.
FUEL COST RECOVERY:
The charge per kWh of the above rate shall be increased by the applicable fuel cost recovery per
kWh as provided in PUCT Sheet No. IV -69.
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill aft= 16 days. If the sixteenth day falls
on a holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE:
Alternating current; 60 hertz; single or three phase, at one available standard secondary voltage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000092
98
XcelEnergy'
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 56 of 75
Section No. IV
Sheet No. IV -181
Revision No. 8 T
Page 1 of 6
TRANSMISSION QF STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at a transmission voltage supplied at
one Point of Delivery, for which Company's service is used as standby, backup or maintenance
service. Applies to Customers who operate any electric generating equipment in parallel with
Company's electric system which normally serves all or a portion of Customer's electrical load
requirements; who requires Standby Capacity from Company, and who desire use of Company's
electrical service for temporary backup or maintenance power and energy. Not applicable to
power generated for resale.
AVAILABILITY: Service hereunder is available only to Customers who have executed an Electric
Service Agreement with Company that specifies Customer's Contract Standby Capacity and
Total Load requirements. All power service supplied by Company to Customer in excess of the
Contract Standby Capacity shall be provided by Company under the Large General Service
Transmission • ("LGS-T") tariff. Service under Company's Interruptible Credit Option (ICO)
tariff is not available to Customers taking service under this Transmission Standby Service tariff
Customers receiving service under this tariff shall be billed on a calendar month basis, such that
the first day of each month shall be the beginning and the Last day of each month shall be the end
of the monthly billing period.
SUB TRANSMISSION STANDBY SERVICE — 69 KV: I
RATE: Service Availability Charge Per Month: $710.00
Transmission Standby Capacity Fee — Summer: $4.54 / kW Month I
Transmission Standby Capacity Fee — Winter. $3.19 / kW Month I
Generation Standby Capacity Fee — Summer: $1.78 / kW Month I
Generation Standby Capacity Fee — Winter: $1.25 / kW Month I
Energy Charge: for all kWh used during the month: $0.004505 per kWh I
TRANSMISSION STANDBY SERVICE -115 KV AND ABOVE:
RATE: Service Availability Charge Per Month: $710.00 I
Transmission Standby Capacity Fee— Summer- 3436 / kW Month I
Transmission Standby Capacity Fee— Winter. $3.06 / kW Month I
Generation Standby Capacity Fee — Summer: $1.72 / kW Month I
Generation Standby Capacity Fee — Winter: $1.19 / kW Month I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000093
XceIEnergy
SOUTHWESTERN FUatrC SEitV:CE
ELECTRIC TARIFF
Attachment B
Page 57 of 75
99
Section No. IV
Sheet No. IV -181
Revision No. 8 T
Page 2 of 6
TRANSMISSION QF STANDBY SERVICE
Energy Charge: for all kWh used during the month: $0.004273 per kWh
EXCESS USAGE — 69 kV
If Customer Usage Hours exceed 99 Usage Hours, the above charges shall not apply and the
charges will be as follows:
Service Availability Charge Per Month: $710.00
Demand Charge - Summer: $11.68 / kW Month
Demand Charge - Winter: $ 8.13 / kW Month
Energy Charge: for all kWh used during the month $0.004505 per kWh
EXCESS USAGE —115 kV AND ABOVE
If Customer Usage Hours exceed 99 Usage Hours, the above charges shall not apply and the
charges will be as follows:
Service Availability Charge Per Month: $710.00
Demand Charge - Summer: $11.16 /kW Month
Demand Charge - Winter: $ 7.81 / kW Month
Energy Charge: for all kWh used during the month $0.004273 per kWh
1
SUNIlVIER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October —May.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000094
100
XceIEnergy-
SOUTOVIESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 58 of 75
Section No. IV
Sheet No. IV -181
Revision No. 8 T
Page 3 of 6
TRANSMISSION QF STANDBY SERVICE
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered thirty -
minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 + customer's power factor x kW
demand) — kW demand) .
DEFINITIONS:
CONTRACT STANDBY CAPACITY:
The level of Contract Standby Capacity in kilowatts the Company reserves in its transmission and
distribution systems and its generation for the Customer as set forth in the Electric Standby
Service Agreement. Contact Standby Capacity is limited to and is the lesser of
• the Customer's Total Load,
• the Customer's generation capacity, or
• an amount agreed to by the Company and the Customer.
Customer's Total Load represents the maximum historical level of electrical demand at the
Customer's service location on or after January l', 2012, and shall be determined by meter
measurement of the total capacity requirements of Customer, regardless of whether such capacity
is supplied by Company, Customer's own generation equipment, or a combination of both.
Customer's Total Load shall carry forward from year-to-year until Customer's maximum demand
exceeds previous Total Load. In the month following the month in which larger total was
metered, the larger value would then become the Customer's Total Load.
STANDBY SERVICE:
Standby Service shall be the service provided by Company under this Transm7ssion Standby
Service tariff.
USAGE HOURS:
Each hour in a calendar month during which a 30 -minute interval of Customer generation is less
than the lower of Customer usage or 60% of Contract Standby Capacity, excluding energy used
during Qualified Scheduled Maintenance Periods, is considered a Usage Hour. If the number of
.X„„o
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000095
/0"
ibelEnergr
SOUTHWUSTrkK PO IOC SE V1C1
ELECTRIC TARIFF
Attachment B
Page 59 of 75
101
Section No. IV
Sheet No. IV -181
Revision No. 8 T
Page 4 of 6
TRANSMISSION QF STANDBY SERVICE
USAGE HOURS (cont.):
Usage Hours in a month is 100 or more hours, Customer billing will be based upon the provisions
of Excess Usage for Standby Service.
CONTRACT PERIOD:
All contracts under this schedule shall be for a minimum period of one year and one-year periods
thereafter until terminated, where service is no longer required, on 30 days notice. Greater
minimum periods may be required by contract in situations involving large or unusual loads.
METER INSTALLATION:
Company shall install, own, operate, and maintain the metering to measure the electric power and
energy supplied to Customer to allow for proper billing of the separate LGS-T Service and
Standby Service demands and energy identified above. In particular, Company will install a
meter that measures the flow of power and energy from Customer's own • generating facility
(generation metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company
may determine that it is more practical or economical to use generation metering installed and
owned by Customer, rather than Company-owned metering equipment If Company, at its sole
discretion, makes such a determination, then Customer -owned generation metering may be used
for the billing purposes, so long as such metering equipment meets Company's standards for
quality and accuracy. If through the course of Company's evaluation of the metering
requirements for the generation meter(s), Company determines, at Customer's generator(s),
Company shall determine the billing for the provision of the Standby Service tariff on an un-
metered
nmetered and calculated basis. This determination can only be made if the only electrical load
located at Customer's site is station power equipment as defined by the Federal Energy
Regulatory Commission.
Regardless of Company's ultimate determination of the requirement (or lack thereof) for
installation of the generation metering, a meter will always be required at the point of
interconnection between Company and Customer and such meter will measure both delivered and
received capacity and energy.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000096
102
XceI Energr
SOUTHWESTERN PUBiIC SERVICE
ELECTRIC TARIFF
Attaclunent B
Page 60 of 75
Section No. IV
Sheet No. IV -181
Revision No. 8
Page 5 of 6
T
TRANSMISSIONQF STANDBY SERVICE
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE:
Qualifying Scheduled Maintenance Periods must occur within the winter months as defined
above. Customer must provide Company with 30 days written notice of scheduled maintens nce
prior to the beginning of the maintenance period. The duration of qualifying scheduled
maintenance periods may not exceed a total of six weeks in any 12 -month period.
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods
4411 result in the energy used during unapproved maintenance outages being applied against the
Usage Hours energy limit.
DEFINITION OF SUPPLEMENTAL DEMAND.
If Customer's Total Load is in excess of the Contract Standby Demand, the Supplemental
Demand (kW) is equal to the Customer's. Total Load minus the Contract Standby Capacity.
Supplemental Demand and energy will be billed on the applicable LGS-T tariff.
FUEL COST RECOVERY:
The charge per kWh of the above rate shall be increased by the applicable fuel cost recovery
factor per kWh as provided in PUCT Sheet No. IV -69. This rate schedule is subject to other
applicable rate adjustments.
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day falls
on a holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE:
Alternating current 60 hertz; at approximately the contract voltage of 69 kV or larger.
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA
Section 39.904(m-1) and Commission's regulations promulgated there under, shall receive a
credit of $0.000191 per kWh to their billings under this tariff. Customers who receive RBC I
credits under this tariff do not share in any REC costs, and shall not be eligible to receive any
revenue credits from sales of RECs by the Company.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000097
XcelEnergy
$OUTHwFSUUN PUBLIC SCIVICE
ELECTRIC TARIFF
Attachment B
Page 61 of 75
103
Section No. N
Sheet No. N-181
Revision No. 8 T
Page 6 of 6
TRANSMISSION QF STANDBY SERVICE
REC CREDIT (cont.):
115 kV Customers who provide written notice to the Commission pursuant to PURA Section
39.904(m-1) and Commission's regulations promulgated there under, shall receive a credit of
$0.000190 per kWh to their billings under this tariff. Customers who receive REC credits under R
this tariff do not share in any REC costs, and shall not be eligible to receive any revenue credits
from sales of RECs by the Company.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000098
104
Xcel Energyt
SOUTHWUSTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 62 of 75
Section No. W
Sheet No. IV -182
Revision No. 9 T
Page 1 of 3
LARGE SCHOOL SERVICE
APPLICABILITY: To all K-12 schools both public and private supplied electric service at primary or
secondary voltage measured through one meter and at one Point of Delivery, where facilities of
adequate capacity and suitable voltage are adjacent to the premises to be served, exceeding 10
kW of demand in any month
Bach year, Company will review the demand of all Customers receiving service under this tariff
If the avera$e of Customer's twelve monthly demands in the immediately preceding calendar
year does not exceed 10 kW, then Customer is not eligible to continue receiving service under
this tarif
Not applicable to standby, supplementary, or shared service, or to service for which a specific rate
schedule is provided.
TERRITORY: Texas service territory.
SECONDARY VQLTAGE:
RATE: Service Availability Charge: $31.30 per month
Energy Charge: $0.009577 per kWh for all kWh used during the month
Demand Charge:
$13.66 per kW of demand used per month during each summer month
$1121 per kW of demand used per month during each winter month
PR]1VIARY VOLTAGE:
RATE: Service Availability Charge: $31.30 per month
Energy Charge: $0.008990 per kWh for all kWh used during the month
Demand Charge:
$11.97 per kW of demand used per month during each summer month
$9.85 per kW of demand used pet month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October throw May.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000099
XlE-nergy"
sautirWUstE rr'Witte SUKV10E
ELECTRIC TARIFF
Attachment B
Page 63 of 75
105
Section No. IV
Sheet No. IV -182
Revision No. 9 T
Page 2 of 3
LARGE SCHOOL SERVICE
ALTERNATE EXPERIMENTAL TIME OF USE RIDER — SECONDARY VOLTAGE
RATE: Service Availability Charge: $32.30 per month.
Energy Charge:
$0.009577 per kWh for all kWh used during all hours, PLUS
$0.142949 per kWh for all kWh used during On -Peak Hours
Demand Charge: $9.67 per kW of demand used per month
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of Tune
through September.
ALTERNATE EXPERIMENTAL TIME OF USE RIDER —PRIMARY VOLTAGE
RATE: Service Availability Charge: $32.30 per month.
Energy Charge:
$0.008990 per kWh for all kWh used during all hours, PLUS
$0.140525 per kWh for all kWh used during On -Peak Hours
Demand Charge: $7.59 per kW of demand used per month
ON -PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Availability limited to a maximum of 50 customers that qualify for service under Large School
Service, secondary and primary voltage combined. Customers must contract for service under this
experimental tariff for a minimum of 12 consecutive calendar months. The On -Peak period shall be
1:00 pm to 7:00 pm, Monday through Friday during the months of June through September. The
Off -Peak period shall be all other hours not covered in the On -Peak period.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000100
106
XcelEnergr
SOIJYHWUIERN PUJLJC se1VICE
ELECTRIC TARIFF
Attachment B
Page 64 of 75
Section No. IV
Sheet No. W-182
' Revision No. 9 T
Page 3 of 3
LARGE SCHOOL SERVICE
DEMAND: Company will furnish, at its expense, the necessary metering equipment to measure
Customer's kW demand for the 30 -minute period of greatest use during the month. In no month,
shall the billing demand be greater than the value in kW determined by dividing the kWh sales
for the billing period by 80 hours.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand exceeding 200 kW. A Power Factor Adjustment will apply to all customers with power
factor metering if the power factor at the time of the highest metered thirty -minute kW demand
interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 customer's power factor x kW
demand)—kW demand)
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh hour as provided in PUCT Sheet
IV -69. This rate schedule is subject to other applicable rate adjustments.
CHARACTER OF SkRVICE: A C; 60 hertz; single or three phase, at one available standard secondary
voltage.
TAM EXTENSIONS: Company will make line extensions in accordance with its standard line extension
Poesy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the nest work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the teams and conditions set forth in Company's Rules, Regulations and Conditions
of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000101
"0„
XceIEnergy *
SOUrH'WESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 65 of 75
107
Section No. IV
Sheet No. W-183
Revision No. 8 T
Page 1 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
AVAILABILITY: This Schedule is available under contract to Customers whose total demand is normally
served by Customer's generation of at least 1,000 kW during June, July, August, and September,
and whose facilities are equipped with appropriate telemetering and control egaipment to permit
Customer to comply with, or Company to implement, curtailment requests. Service under this rate
is available when taken in conjunction with service under the applicable large general service rate
schedules and riders, or with firm standby service under the Transmission Qualifying Facility
Standby Service rate schedule.
APPLICABILITY:
Under contract for electric service to a Qualifying Facility ("QF") provided at a transmission
voltage for which Company's service is used as non-firm standby backup or non -firth maintenance
service supplied at one Point of Delivery.
RATE:
SUB TRANSMISSION SERVICE OF 69 KV:
Service Availability Charge Per Month: The following charge will apply if non-fum standby
service is provided on a stand-alone basis: $710.00
Delivery Charges:
Transmission System Standby Capacity Fee -Summer: $4.54 per 4CP kW
Transmission System Standby Capacity Fee -Winter: $3.19 per 4CP kW
Generation System Standby Capacity Fee- Summer: $1.43 per kW of Nominated
Standby Capacity
Generation System Standby Capacity Fee- Winter: $1.00 per kW of Nominated
Standby Capacity
I
I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGI LATORY AFFAIRS
000102
108
Xcel Energy
SOUTHWESTERN FUV[IC SERVICE
ELECTRIC TARIFF
Attachment B
Page 66 of 75
Section No. IV
Sheet No. IV -183
Revision No. 8 T
Page 2 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
TRANSMISSION SERVICE OF 115 KV AND ABOVE:
Service Availability Charge Per Month: The following charge will apply if non-firm standby
service is provided on a stand-alone basis: $710.00 I
Delivery Charges:
Transmission System Standby Capacity Fee -Summer: $436 per 4CP kW I
Transmission System Standby Capacity Fee -Winter: $3.06 per 4CP kW I
Generation System Standby Capacity Fee- Summer: $138 per kW of Nominated I
Standby Capacity
Generation System Standby Capacity Fee- Winter: $0.95 per kW of Nominated I
Standby Capacity
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through. May.
Usage Rates:
Demand Charge:
There will be no additional demand charge for use of Standby Service except
for Non -Compliant use as defined herein. In this case, Standby Service
Demand Charges shall be as defined in the Non -Compliance Payment
paragraph of this tariff.
Energy Charge:
All Standby Replacement Energy provided by Company during non -interrupt
periods shall be billed at the Hourly Clearing Price of the applicable regional
wholesale energy market. Additionally, an Energy Margin of five percent (5%) of
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000103
'0„
XeelEnergy-
SOtlTNWESFERN PIJ$LIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 67 of 75
109
Section No. IV
Sheet No. IV -183
Revision No. 8 T
Page 3 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRIVI STANDBY SERVICE
Energy Charge (cont.):
the Hourly Clearing Price, shall be added to the charge for all Standby
Replacement Energy provided by Company. Total charge shall not be less than
$0.004505 per kWh at 69 kV or $0.004273 per kWh at 115 kV and above.
BACKUP SERVICE:
Backup Service is capacity and energy supplied by Company to replace Customer's generation
during an unscheduled outage. The maximum required level of Backup Demand (the "Standby
Capacity") shall be nominated annually in writing at least 30 days before the beginning of the
calendar year.
MAINTENANCE SERVICE:
Maintenance Service is capacity and energy supplied by Company to replace Customer's self
generation during scheduled outages of Customer's generation. Scheduled outages shall be set at a
time mutually agreeable by Customer and Company, excluding June, July, and August. The
scheduled outage(s) shall be scheduled in two billing months per calendar year. Scheduled outages
shall be agreed to in writing at least 30 days prior to the beginning of the month in which the
scheduled outage is planned to take place.
SUPPLEMENTAL GENERATION SERVICE:
Supplemental Generation Service is capacity and energy supplied by Company and used by
Customer in place of Customer's self -generation whenever Customer's self -generation is not
operating at the full level of the nominated Standby Capacity. This Supplemental Generation
Service usage shall be billed Standby Replacement Demand and Standby Replacement Energy as
described below.
SUPPLEMENTAL LOAD SERVICE:
Supplemental Load Service is capacity and energy supplied by Company to Customer for load
requirements above the nominated Standby Capacity for Customer's self -generation, in order to
meet Customer's total load requirement. This Supplemental Load Service usage shall be billed in
accordance with the standard applicable rate schedule.
DEFINITION OF CUSTOMER METER DEMAND:
Customer Meter Demand shall be the demand in kW determined from Company's demand meter at
the Customer Meter for the 30 minute period of greatest use during the month.
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000104
110
XceI Energy
SOUTHWESTERN pUSLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 68 of 75
Section No. IV
Sheet No. IV -183
Revision No. 8 T
Page 4 of 6
TRANSMLSSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
DEFINITION OF 4CP DEMAND:
The 4CP Demand applicable under the Delivery Charges shall be the average of the Standby
Replacement Demand at the time of Company's system peak demand in June, July, August and
September of the previous calendar year. Retail Non -Fina Standby Customers without previous
history on which to base their 4CP Demand will be billed based on an estimate of the 4CP
Demand.
DEFINITION OF MINIMUM GENERATION PRODUCTION:
The Mini nam Generation Production shall be the generation output in kW determined at the QF
Generation Meter for the 30 -minute period of least total generation output during the month.
DEFINITION OF STANDBY REPLACEMENT DEMAND:
The Standby Replacement Demand shall be equal to the minimum of (a) Customer Meter
Demand, (b) the Standby Capacity (Backup Demand), or (o) the nominated Standby Capacity
minus the Minimum Generation Production.
DEFINITION OF STANDBY REPLACEMENT ENERGY:
The Standby Replacement Energy shall be equal to the energy metered at the Customer Meter
less the energy supplied to Customer's Supplemental Load Service, but not more than the outage
hours in a month times (multiplied by) the nominated Standby Capacity.
DEFINITION OF SUPPLEMENTAL LOAD DEMAND:
The Supplemental Load Demand shall be equal to Customer Meter Demand minus the Standby
Replacement Demand, but no less than the minimum demand set forth in the applicable tariff.
MINIMUM CHARGE:
The minimum charges in a month shall be the sum of the Service Availability Billing Charge,
Service Availability Charge per Meter if applicable, and fhe Delivery Charges.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW_ A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered thirty -
minute kW demand interval is less than 90 percent lagging. based upon:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000105
XcelEnergr
4011111W, MEM Mire SERVICE
ELECTRIC TARIFF
Attachment B
Page 69 of 75
111
Section No. IV
Sheet No. IV -183
Revision No. 8 T
Page 5 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
POWER FACTOR ADJUSTMENT (cont):
Power Factor Adjustment Charge = Demand charge x ((0.95 _ customer's power factory kW
demand.)- kW demand)
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day falls
on a holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE:
Alternating current; 60 hertz; at approximately the contract voltage.
GENERAL CONDITIONS:
Customer understands that failure to interrupt this Non -Firm Standby Service when requested
threatens the reliability of service to other customers. Company will attempt to provide as much
prior notice as possible prior to interruptions. Interruptions may be made at any time, in the
judgment of Company, when demand for electricity exceeds or is likely to exceed Company's
available electric supply for any reason including, but not limited to, breakdown of generating
units, transmission equipment or other critical facilities; short or longterm shortages of fuel or
generation, transmission, and other facilities; and requirement or orders of governmental
agencies.
CONDITIONS OF SERVICE: .
Customer is required to install, own, operate and maintain necessary monitoring devices and
int ruptei tion -control equipment including protective devices, at Customer's point of delivery, as
reasonably specified by Company. In addition, Company shall install interruption -control
equipment on the Company's side of the point of delivery as it reasonably determines is necessary
to interrupt the interruptible load. All interruption -control equipment shall be under the exclusive
control of Company, and the installation and maintenance of such facilities shall be at the expense
of Customer. Interruption -control equipment consists of, but is not limited to, under -frequency
relays, switchgear, remote control and communications equipment including a communications
path, timers, trip counters, and/or other devices as specified by Company. Remote control and
communications equipment includes equipment necessary to provide instantaneous load
information to Company's designated system operating centers. Operation of the equipment will
remain under the control of Company and Company reserves the right to inspect and test all
interruption -control equipment and review Customers' maintenance records. Customer will make
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000106
112
XcelEnergr
SOUTHWESTERN PUULVG SERVICE
ELECTRIC TARIFF
Attachment B
Page 70 of 75
Section No. W
Sheet No. W-183
Revision No. 8 T
Page 6 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
CONDITIONS OF SERVICE (cont):
commercially reascmable efforts to notify the Company of the timing and anticipated duration of
planned outages.
NON-COMPLIANCE PAYMENT:
When Company requests a reduction of any part or all of Customer's Standby load, Customer must
comply with such request within the specified time period. If, at any time, Customer fails in whole
or in part to maintain the requested load reduction, Customer shall pay the following charges:
1. During interrupt periods called under Company's Interruptible Rate Rider,
Customer shall pay Company's identifiable additional cost for capacity and
150% of the Hourly Clearing Price of the applicable regional wholesale energy
market for energy for any Standby Replacement Demand and Energy used by
Customer, plus any charges or penalties imposed by any governing entity that
result from Customer's non-compliance. In the absence of identifiable additional
capacity cost, Customer shall pay 150% of the firm demand charge in accordance
with the Transmission Qualifying Facility Standby Service rate schedule for the
amount of demand not interrupted during the billing month.
2. If Customer fails to comply twice in any twelve month period, Customer shall
pay the same charges as just described, except that the demand charge shall be an
amount equal to the normal firm demand charge in accordance with the
Transmission Quaalifying Facility Standby Service rate schedule for the amount
of demand not interrupted during the billing month, multiplied by a factor of
twelve. Additionally, a second non-compliance event during a Capacity Control
interrupt period in any twelve month period shall result in the Customer being
removed from the Non -Firm Standby Service tariff and Customer ehall not be
eligible to return to this tariff for one year.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000107
r
XCei Enerq '"'
JOUTHW2s7IRH PUBLIC SEIYICE
ELECTRIC TARIFF
Attachment B
Page 71 of 75
Section No. IV
Sheet No. IV- 205
Revision No. 1
Page l of 2
113
GENERAL SERVICE — Experimental Time of Use Rate
APPLICABILITY: Optional rate limited to a combination of 250 commercial and industrial electric
service customers supplied at either secondary or primary voltage at one Point of Delivery and
measured through one meter, where facilities of adequate capacity and suitable voltage are
adjacent to, the premises to be served, in excess of 10 kW of demand.
If Customer elects service under this rate schedule, Customer must continue to take service
under this optional rate for a minimum of 12 consecutive months.
Each year, Company will review the demand of all Customers receiving service under this
tariff. If the average of Customer's twelve monthly demands in the immediately preceding
calendar year does not exceed 10 kW, then Customer is not eligible to continue receiving
service under this tariff.
Not applicable to standby, supplementary, resale or shared service, or service to oil and natural
gas production Customers.
TERRITORY: Texas service territory.
RATE:
ON PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June through September. The Off -Peak period shall be all other hours
not covered in the On -Peak period.
OFF-PEAK HOURS: All hours other than On Peak Hours described in this rate schedule.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000108
Secondary Voltage
Primary Voltage
Service Availability Charge
$26.60
$59.50
Energy Charge, All Hours
$0.007783
$0.005960
Energy Charge, On Peak Adder
$0.131370
$0.108932
Demand Charge
$10.68
$8.82
ON PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June through September. The Off -Peak period shall be all other hours
not covered in the On -Peak period.
OFF-PEAK HOURS: All hours other than On Peak Hours described in this rate schedule.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000108
114
XceI Energy-
SOUTHWESTERN PUBLIC SERVICE
ELECTRIC TARIFF
Attachment B
Page 72 of 75
Section No. IV
Sheet No. IV- 205
Revision No. 1 T
Page 2 of 2
GENERAL SERVICE —Experimental Time of Use Rate
DEMAND: Company will furnish, at Company's expense, the necessary metering equipment to
measure the Customer's kW demand for the 30 -minute period of greatest use during the month.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with,
demand exceeding 200 kW. A Power Factor Adjustment will apply to all customers with
power factor metering if the power factor at the lime of the highest metered thirty minute kW
demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 y customer's power factor x kW
demand) — kW demand)
FUEL COST RECOVERY AND ADJUSTMEN'T'S: The charge per kWh shall be increased by the
applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate
schedule is subject to other applicable rate adjustments.
CHARM-nat. OF SERVICE: A -C; 60 hertz single or three phase, at one available standard
secondary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations and
Conditions of Service on file with the Public Utility Commission of Texas. A Contract may be
required by the Company to be executed prior to extending service if Customer's load is expected
to be greater than 200 kW. The contract term shall contain a minimum contract period with an
automatic renewable provision from year to year thereafter.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000109
XceIEne
SOUTrWESTEEN PUatrC SERVICE
ELECTRIC TARIFF
115
Attachment 13
Page 73 of 75
Section No. IV
Sheet No. IV- 206
Revision No. 1 T
Page 1 of 3
GENERAL SERVICE — Low Load Factor Rate
APPLICABILITY: Optional rate for commercial and industrial electric) service customers supplied at
secondary or primary voltage at one Point of Delivery and measured through one meter, where
facilities of adequate capacity and suitable voltage ate adjacent to the premises to be served, in
excess of 1,000 kW of demand, and load factors of 25 percent or less.
If Customer elects to take service rimier this optional rate schedule, customer must remain on
this rate schedule for a minimum of twelve consecutive calendar months
Not applicable to standby, supplementary, resale or shared service, or service to oil and natural
gas production Customers.
LOAD FACTOR: Determined by dividing Customer's monthly metered kWh in each billing cycle by
the product of the Customer's maximum kW demand times 24 hours per day of the billing
period. (kWh / (kW x 24 x days in billing period) Customer's load factor will be reviewed each
calendar year. If Customer's average monthly load factor exceeds 25 percent for the previous
calendar year, Customer will be moved to applicable general service rate for a minimum of 12
consecutive months. Customer's load factor can be re-evaluated for qualification for this rate
schedule after each calendar year.
TERRITORY: Texas service territory.
RATE:
ON[ PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June through September. The Off -Peak period shall be all other hours
not covered in the On -Peak period..
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000110
Secondary Voltage
Primary Voltage
Service Availability Charge
$26.60
$59.50
Energy Charge
$0.007783
$0.005960
Demand Charge, All Hours
$5.65
$5.26
Demand Charge, On Peak Adder
$21.12
$2030
ON[ PEAK HOURS: 1 p.m. through 7 p.m., Monday through Friday during the months of June
through September.
Customers must contract for service under this experimental tariff for a minimum of 12
consecutive calendar months. The On -Peak period shall be 1:00 pm to 7:00 pm, Monday through
Friday during the months of June through September. The Off -Peak period shall be all other hours
not covered in the On -Peak period..
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000110
116
re), XcelEnew
SOUTHWSSTERN PUHHIC SEJYJCF
risk -nue TARIFF
Attachment B
Page 74 of 75
Section No. IV
Sheet No. IV- 206
Revision No. 1
Page 2 of 3
GENERAL SERVICE — Low Load Factor Rate
OFF-PEAK HOURS: All hours other than On Peak Hours described in this rate schedule.
DEMAND: Company will furnish, at Company's expense, the necessary metering equipment to
measure the Customer's kW demand for the 30 -minute period of greatest use during each month
and the 30 -minute of greatest use during on -peak hours each month.
ON PEAK BILLING DEMAND: The greater of the maximum demand reading during the on -peak
hours of the current month or 100% of the highest measured demand established in the billing
months of June through September in the twelve (12) month period ending with the current
month. The On -Peak Demand Charge is only applied during the months of June through
September.
POWER FACTOR ADJUSTMENT: Company will install power factor metering for Customers with
demand expected to exceed 200 kW. A power factor adjustment charge shall apply to all
customers with power factor metering if the power factor at the time of the highest metered
thirty -minute kW demand interval is less than 90 percent lagging, based upon:
Power Factor Adjustment Charge = Demand charge x ((0.95 _ customer's power factor x kW
demand) - kW demand)
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh shall be increased by the
applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate
schedule is subject to other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard
secondary voltage.
LINE .L.XTENSIONS: Company will make line extensions in accordance with its standard line
extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth clay falls on a holiday or weekend, the due date will be the next work day.
_.a
f -CL -1. --
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000111
XcelEnergr
sautNWEsTERK roBire $E VICE
ELECTRIC TARIFF
Attachment B
Page 75 of 75
Section No. IV
Sheet No. IV- 206
Revision No. 1
Page3 of 3
117
T
GENERAL SERVICE — Low Load Factor Rate
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule
is subject to the terms and conditions set forth in the Company's Rules, Regulations and
Conditions of Service on file with the Public Utility Commission of Texas. A Contract may be
required by the Company to be executed prior to extending service if Customer's Load is expected
to be greater than 200 kW. The contract term shall contain a minimum contract period with an
automatic renewable provision from year to year thereafter.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
000112
118
Attachment C
Page 1 of 4
ATTACHMENT C TO UNOPPOSED STIPULATION
Regulatory Asset for Power Factor Adjustment Charge Revenue
1. The purpose of the Power Factor Adjustment Charge Revenue Regulatory Asset
("Asset") is limited to tracking the differential, if any, between the amount of revenue
directly related to the power factor adjustment charge assumed to be part of the present
revenues in Paragraph I.a. of the Stipulation, $12,599,674 per year, and the actual level of
power factor adjustment charge revenue SPS collects under the rates established under
the Stipulation in this case, Docket No. 45524.
2. SPS will record, as a regulatory asset, on a monthly basis the differential between the
baseline level of power factor adjustment charge revenue set forth in Attachment C-1
("Baseline Revenue") and the actual level of power factor adjustment charge revenue
("Actual Revenue") under the rates set in Docket No. 45524. The monthly differential
("Differential") and cumulative Differential between Baseline Revenue and Actual
Revenue, positive and negative, will be recorded by customer class. In effect, there will
be a Differential for each class that pays a power factor adjustment charge and, thus, a
potential regulatory asset for each class. Entries recorded in the Asset will reflect the
Differentials for usage on and after July 20, 2016 through the earliest of: (a) the day
before the relate -back date (PURA § 36.211) of the rates in SPS's next base rate case; (b)
the effective date of the new rates, whether interim or permanent, in SPS's next base rate
case; or (c) July 19, 2018.
Baseline Power Factor Adjustment Charge Revenue
3. The annual Baseline Revenue shown by month and by class is set out in Attachment C-1.
For a true -up period that is less than twelve months (a twelve-month period being July 20
of a year through July 19 of the next year), the annual Baseline Revenue will reflect: the
prorated revenue for July (see Paragraph 4 below); the monthly Baseline Revenue as
shown on Attachment 1 for the months of August until the start of the ending month: and
PUC Docket No. 45524; SOAH Docket No. 473-16-2520
Unopposed Stipulation
Attachment C
Page 1 of 4
000113
119
Attachment C
Page 2 of 4
then for the ending month the Baseline Revenue will be prorated to reflect the number of
days in the month the rates set in Docket No. 45524 are in effect.
4. For the month of July 2016, the Baseline Revenue will be prorated to reflect that the rates
set in Docket No. 45524 will apply to usage for only 12 days of the month (July 20th —
313), or 38.71% of the monthly usage. For the month of July 2017, the Baseline Revenue
will be prorated, with the first 19 days of the month, or 61.29% of the monthly usage,
applicable to the annual period July 20, 2016 — July 19, 2017, and the last 12 days of the
month, 38.71% of the monthly Baseline Revenue, applied to the true -up period starting
July 20, 2017. If the end of the period for recording an Asset as described in Paragraph 2
of this Attachment C has not sooner occurred, July 2018 will be prorated the same. For
the last month the Asset is recorded, the Baseline Revenue will be prorated to reflect the
number of days in the month the rates set in Docket No. 45524 are in effect. The total
amount of the Asset will not exceed the Differential between Baseline Revenue and
Actual Revenue for the entire period, which may be up to 24 months, for which the Asset
is calculated.
Calculation of Regulatory Asset and Implementation of Surcharge
5. Calculation of Surcharge —
a. It is a prerequisite for recovery of any surcharge that SPS has collected less power
factor adjustment charge revenue in total for the applicable period than is
reflected in the total Baseline Revenue amount for that period, which is described
in Paragraph 3 of this Attachment C.
b. In no event will the total actual power factor adjustment charge revenues plus the
amount of the surcharge exceed the total Baseline Revenue amount for the
applicable period.
c. Any surcharge will apply only to those classes for which total Actual Revenue for
the applicable period is less than total Baseline Revenue. The surcharge amount
for each such class will be based on the Differential for that class, reduced
PUC Docket No. 45524; SOAH Docket No. 473-16-2520
Unopposed Stipulation
Attachment C
Page 2 of 4
000114
120
Attachment C
Page 3 of 4
proportionally among those classes to the extent necessary to comply with
Paragraph 5.b.
6. Implementation of Surcharge
a. Subject to Commission approval, and subsequent true -up, SPS will implement an
interim surcharge by class to recover the Differential for the period July 20, 2016
through July 19, 2017 through an interim rate rider that will begin no later than
July 2018 and end no later than July 2019. SPS will file an application for the
interim rider by December 29, 2017.
b. Subject to Commission approval, SPS will update the interim rate rider
established under Paragraph 6.a. to ensure that the rider recovers no more than the
total Differential between Baseline Revenue and Actual Revenue for the period
starting July 20, 2016 through the end of the period for recording an Asset as
described in Paragraph 2 of this Attachment C ("Residual Amounts"). The
starting date and ending date of the updated rate rider will be set to ensure that
SPS recovers or refunds the Residual Amounts within 24 months of the months in
which they would have been billed. SPS will file an application for the updated
rider within six months of the end of the period for recording an Asset as
described in Paragraph 2.
7. No party will oppose SPS's requests to implement the surcharges as described in this
Attachment C, subject to SPS demonstrating that: (i) the amounts recorded in the Asset
were properly recorded and accurately calculated under the terms of this Attachment C;
(ii) as provided in Paragraph 5 of this Attachment C, SPS collected less total Actual
Revenue for the applicable period than is reflected in the total Baseline Revenue amount
for that period, which is described in Paragraph 3 of this Attachment C; and (iii) as
provided in Paragraph 5, the total Actual Revenues SPS collected for the applicable
period plus the amount of the surcharge do not exceed the total Baseline Revenue amount
PUC Docket No. 45524; SOAH Docket No. 47346-2520
Unopposed Stipulation
Attachment C
Page 3 of 4
000115
121
Attachment C
Page 4 of 4
for that period. Parties reserve their rights regarding the rate design of the interim rate
rider and updated rate rider, and any true -up mechanism.'
1 To the extent that SPS demonstrates it is entitled to implement a surcharge under the terms of this Attachment
C, the surcharge will be assessed on a class -by -class basis as described in this Attachment C. For the avoidance of'
doubt, in no event shall any of the Asset amounts be recovered from classes other than those listed in Attachment C-
1.
PUC Docket No. 45524; SOAH Docket No. 473-16-2520
Unopposed Stipulation
Attachment C
Page 4 of 4
000116
Southwestern Public Service Company
Estimate of Monthly Power Factor Adjustment Billings at Uncorrected Levels - Texas Retail
For the Test year ended December 31, 2015
Docket No. 45524
Attachment C-1
Page 1 of 1
Winter Winter Winter Winter Winter Summer Summer Summer Summer Winter Winter Winter
Winter Power Summer Power
January February March April May June July August September October November December Factor Billings Factor Billings
Secondary General NCP kW 370,047 258,609 250,868 286,746 317,871 349,157 420,040 447,270 390,886 375,178 312,595 328,768
Monthly share of Season 14.80% 10.34% 10.03% 11.47% 12.71% 21.72% 26.13% 27.83% 2432% 15.00% 12.50% 13.15%
Estimated Uncorrected
Power Factor Charges S 328,463 S 229,480 S 222,600 5 254,559 S 282,079 5 245,141 S 294,914 S 314,101 S 274,486 S 332,902 S 277,418 $ 291,844 5 2,219,347 S 1,128,643
Primary General NCP kW 260,738 239,542 235,569 244,759 246,359 252,038 258,280 276,961 299,905 237,732 254,490 243,841 S 2,026,007 S 1.486,072
Primary Standby NCP kW 863 747 664 709 610 726 737 718 704 679 900 998 S 1,826 S 1.607
SAS -4 NCP kW 19,143 16,977 19,849 20,133 19,637 24,052 23,907 23,945 23,281 22,861 18,110 18,663 5 - $ -
SAS -8 NCP kW 3,376 4,657 4,787 5,664 5,442 5,395 4,297 5,353 4,622 5,400 6,864 6,344 S 111,996 S 82,085
SAS -13 (LLF) NCP kW 3,477 3,402 49 3,676 3,444 65 2,804 2,892 65 3,527 84 83 S 4,334 S 9,805
Total Primary Service NCP kW 287,595 265,325 260,918 274,941 275,492 282,276 290,026 309,869 328,577 270,198 280,448 269,928 S 2,144,163 S 1,579,569
Monthly share of Season 13.16% 12.14% 11.94% 12.58% 12.61% 2331% 23.95% 2539% 27.14% 12.37% 12.8456 12.35%
Estimated Uncorrected
Power Factor Charges 5 282,199 S 260,326 $ 256,040 S 269,763 S 270,406 S 368,236 S 378,346 S 404,253 S 428,734 S 265,260 $ 275,338 S 264,831 5 2,144,163 S 1,579,569
LGS-T,69kV NCP kW 77,188 76,204 79,246 78,175 77,502 81,536 79,472 77,277 81,523 78,940 79,360 76,153 S 648,067 S 552,125
69 kV Standby NCP kW 7,692 3,446 7,069 2,111 7,144 2,526 605 7,869 7,673 3,421 3,478 7,088 S 68,105 S 42,040
SAS -12 NCP kW 78,135 71,306 65,835 69,142 66,633 64,264 68,973 81,032 65,107 70,467 68,460 74,600 included in LOS -T, 69 kV
Total LGS-T 69 kV NCP kW 163,016 150,956 152,149 149,428 151,280 148,327 149,049 166,179 154,304 152.828 151,298 157,841 S 716,171 S 594,166
Monthly share of Season 13.27% 1228% 1238% 12.16% 1231% 24.01% 24.12% 26.90% 24.97% 12.44% 12.3156 12.85%
Estimated Uncorrected
Power Factor Charges S 95,036 5 87,946 S 88,662 S 87,086 S 88,161 S 142,659 S 143,313 $ 159,831 S 148,363 S 89,092 S 88,161 S 92,028 S 716,171 S 594,166
LGS-T, 115 kV+ NCP kW 632,985 646,785 619,169 627,216 626,474 653,618 649,478 625,560 635,438 619,171 608,102 636,206 5 2,108,192 $ 1,671,545
115 kV+ Standby NCP kW 16,072 16,653 31,487 14,361 22,824 15,470 16,429 15,251 14,873 14,026 14,084 18,919 S 93,789 S 115,823
Total LGS-T 115 kV+ NCP kW 649,057 663,438 650,657 641,577 649,299 669,088 665,907 640,811 650,381 633,197 622,186 655,125 S 2,201,981 S 1,787,368
Monthly share of Season 12.56% 12.85% 12.60% 12.42% 1237% 25.48% 2536% 24.40% 24.76% 12.26% 12.05% 12.69%
Estimated Uncorrected
Power Factor Charges S 276,569 5 282,955 S 277,450 S 273,486 S 276,789 S 455,421 $ 453,277 S 436,118 $ 442,552 5 269,963 S 265,339 5 279,431 5 2,201,981 S 1,787,368
Lg. Municipal Service NCP kW 21,301 18,367 21,277 22,473 21,906 21,720 25,120 27,406 26,661 18,651 18.585 18,343 5 69.752 S 50,836
Lg.Municipal- Primary NCP kW 2,917 2,800 3,809 4,687 3,541 4,537 4,612 4,504 4,817 3.803 2,953 3,228 S 11,502 S 9,220
Total Large Municipal NCP kW 24,218 21,167 25,085 27,161 25,448 26,257 29,733 31,910 31,479 22,454 21,538 21,570 5 81,253 5 60,056
Monthly share of Season 12.84% 11.22% 13.30% 14.40% 13.49% 21.99% 24.91% 26.73% 2637% I1.90% 18.4294 11.43%
Estimated Uncorrected
Power Factor Charges S 10,433 S 9,117 5 10,807 5 11,700 S 10,961 S 13,206 5 14,960 S 16,053 S 15,837 $ 9,669 S 9,279 $ 9,287 $ 81,253 S 60,056
Lg. School Service NCP kW 41,659 37,130 38,794 38,939 44,026 28,891 36,745 63,210 65,820 51,286 43,107 37,196 S 36,569 S 49,400
Large School -Primary NCP kW 554 555 669 718 806 566 708 1,109 1,054 968 688 582 S 397 5 592
Total Large School NCP kW 42,213 37,685 39,462 39,657 44,833 29,457 37,453 64,319 66,874 52,255 43,795 37,778 5 36,965 5 49,992
Monthly share of Season 12.50% 11.16% 11.69% 11.74% 13.28% 14.87% 18.91% 32.47% 33.75% 15.47% 12.97% 11.19%
Estimated Uncorrected
Power Factor Charges S 4,621 S 4,125 S 4,321 S 4,340 S 4,909 5 7,434 S 9,453 5 16,232 S 16,872 5 5,719 S 4,794 S 4,136 S 36,965 S 49,992
O
Source for NCP kW: Schedule O -U1.4, worksheet "Adj NCP at meter". LGS-T 69 kV includes SAS -12.
Total Power Factor Billings S 7,399,881 S 5,199,793
S 12,599,674
check S 0
PUBLIC I2rrtITY COMMISSION Or TEXAS
SPUTHW10i:tRN FOLIC S87[YICSCOMPA10Y
PUCDOCKET NO.43574
TTS7WWI ENDING 12131/2010
Compromise
PCRF Baselines
PPCss
APC
0S14.a
oaC
ROB.
PCAET.s
PCPIr.
?car
CBD.
CBP. RASIS
PORP Bamitnes
P
-14
Moths
Small
Owed
30.14.
6.aamm7
Ousel
Swim
6.+s feted
abob
11mIcipd
84.1.1
14,11 d da4
6 .1
Ptissry 6odry
Saws Santa
1aep
Wad
Prism
Iq
feted
saws.
!Sow
Omni
&Enke
la=ate
14.14.
74.rieta
69-113 ■Y
Attachme.
Page 1 of 5
34!34,026 11437,171 4.404,216 16162.137 1,679,913 11202.361 39,709 103,571 316,435 11382 174,517 4.724,470 3.081,492 13.433,931 11,406 67,570
0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0
401,411 -113.29 .40242 -134,071 -15,350 -1033.71 -346 -963 -3.331 404 7,991 43411 -21,136 -123,763 401 417
413,319,403 94.341,214 34,130,661 130571,946 13.016,914 17,514748 443,327 313,793 4,514,529 10,307 6,777,342 52.143,396 23,179,776 101,120,607 013,191 337,629
00770 00770 0.0770 00770 0.0770 0.0770 0.0770 0.0770 0.0770 0.0770 0.0710 0.0770 0.0770 00770 90770 0.0770
27,774123 6,304297 3.721,716 1,533,013 130,133 5.719,552 33.256 33,273 296,765 3,760 442,314 3,403139 1.339,307 4,799,339 44,731 34,194
11,911119 7671,14. 994.191 3,645,351 363,826 7490330 13,719 33263 130,12 3131 193,266 11191,947 611,344 2,902.944 19,314 15,514
7,207,013 1,939,339 713,650 2.653117 234.371 1161,031 14.332 15,172 87,530 1659 156299 611,937 291,909 1232.671 30,123 26,973
1463,461,176 753,034.449 2,411,497,673 27612,311 6,185,403 1112.030 13431 491,173 3.974 706,170 4116,17 1,191.130 1,619,701 34,036,308 24,717,363
KWH KWH KWH 19.11 KW KYM 9)4 KW KW KW KW KW KW KWH 10/21
PPC. P0aesad poser scarily cora 6am.esities t stare eaaMFJte.La]iaat.dto tba am dura andte.d Is am bps nem hem mtevl*iph ladmmpmdtm+i,s bae.ue pmmedn0
APC Pwdwad rasa eapao4malr Erma 01311stm Mlacami Iol1atate dap sad used d i0 bow rata 00011tem71gs lam m.opctsmos tate-nm pootscafie♦.
0524. FIv_Fm Ems Ada* 01701101 dlucdaltottt este dap ad wad m a1 ban Wm hem the 14.!14310 lam mrsracIessin tes.am ptm.dss.
PC1C.a Net production apdilmeped wad a0aaao3 m 6. ram dm lad wad toed but past Dem cots mites last mtapat .sin bu-oE peamtdin&.
ROI. 778; Mamas Ns of nun te.dtoad bus .tars hemtte uaiiq't lad mepm.Lmdrs base rota psamodnl.
PCD@.s Depm laSm.apsgsaclodtoroepeaBrtimcapacity, dimmed tomiteniclan sod mod toact Ism noltsham14a.t1lty'iIsm samptd.mwbua+prptomddf.
PCF17m Faecal *.ow ta, u MOM to ad prokstmsa wacky mreds3 apt.,.0oeed as the sae dm missal to ass tam este hos dmvOtys/art .-,ache siv !&mean. pto®d140.
PCOre Odatr Mum u related to sid modod3a0 scagitithwatad wad, Mocalsd to Bs oft dot int seal to ad bast atm Bum dm stElly'sbU&pule._ abuo1016pteeeehes.766includesptapttppa.pm.a mm My ad srommesa 0
CBD. Reism st PCRF notre diaskalEastbtaavm.
TcRPBaselines
F0iuc UTILITY COMM15110110F7[7t6
5[4DIRW0f11Rn FNi11c IUVIC[ COMPAINY
PucPoat=711o.4SA4
YI,AR MMDI14O 120112015
Compromise
TCRF Baselines
Attachment D
Page 2 of 5
Paws
Gina
kinue
Lap Gm=
Una
69.113 kV
Line General
Sanas
7,-
1134iV
00eo
1
32�Fo6
TIC 661433,271 112,417,691 34,336,190 206,722,344 204642416 139,710,673 736,719 1314,114 7334,172 140,116 10,100,434 22011.912 36,139973 137,244,407 1460321 110439
ROA 00720 00770 00770 09770 10710 0.0770 01770 40770 0.0710 0.0770 40770 0.0770 0.0710 0.0770 00770
RTIC 31,471476 11,741399 4,176,217 13,917,616 1,119,466 10.737.772 31,347 101,192 344,747 10,719 131,03 6346,436 2,036216 11710,699 11,643 62,407
TD11PK 23,700,131 3406,134 1923,127 1,329311 731,941 4,933,074 26,632 46,399 200463 4,900 312,944 3,014,610 1,304.913 1.377.007 37.197 20.734
TM 17,316.670 3,914,791 1,472,109 3339,413 339,337 3496,167 20,930 74,221 191,633 2,673 216.603 2,264922 919410 4473474 27,101 27,414
TOT (I) 0,340,917 2,043,644 743.531 3.717,294 213.107 1.079.093 13,367 17,047 94,366 1,794 134,627 961,419 410497 1,767,419 21.960 11,252
TCRW 47,102.741 .0,206,013 -4,699,437 -17,907470 -1,716421 -12467,441 45,607 -113,774 433,413 42.993 434,43 -7,333,991 4,194,479 -13,02273 02,016 -70,461
rem* 43.141460 9.172,690 3416,303 12419,201 1311,124 9,130,601 72.969 13,947 411,179 1,176 721,307 2,440,421 7,331,721 9299,144 76,996 61,943
ATC 33,102404 12,210,133 4340.179 14731,714 1,632,437 11,171,116 60,422 103,031 314724 11,213 444211 6,719434 2937.731 12443,646 b,08 0,013
ALLOC 10006 1004 100% 10096 100% 100% 100% 10096 10096 100% 100% 10006 100% 10076 10096
a1.eA1LOC 31132306 6237006 31.0393% 3.1927% 219112% 0.1173% 1197516 1.104014 0410096 1.639214 1164406 3.419614 23709291 4167006 0.1313%
RA 96,720,466 22,013,731 7,937,114 31284,913 3,046,910 20321,177 113,411 191,904 1467,144 19,344 1.313477 12339,176 3301,961 23,344792 162039 116,959
BD 1,643.441,171 733,036,449 2,411477.633 276,622.11 6,212403 11,022070 13,431 491,173 1,974 706.170 4,06,170 1,191,139 0469,761 34,026301 24.717.293
RD RASE KWH KWHI MN 19.74 KW MR KW KW KW KW /:W LW KW KWH KW%
(I) TOT inks puma 423, urn mania Ic,, ad can moi= tax
LPUBLICIf11L27Y COMMISSIOf` 0PTEXAS
SOUTOWX,SItRN 0139214 B[1ONCE COMPANY
POC DO[1111OT N0, 43324
YEAR ENDING 12731/1116
Compromise
DCRF Baselines
357900,333
07700
24.171.417
10,471336
1 714,936
70.316.937
..33,0.3
161014
70.1
Smile
DCRF Baselines
5r6115314331 Imp 1.0,1
1.+3+07 a S..o lr,:=>sI 5104=911
Gold - Pilaw S.m6r7
S.ria ; Suri. 3.1460 SnW
3
Peart
Srr1.
Ia1.
Sokol
s1o16r7
Srrks
Primoy
Gown'
Serb
Attachmei.. _.
Page 3 of 5
Lap Gamma
Sorrio
7L...IJw
IIS+kV
Am
1.41344
137973,459 44443964 113.130,321 11,691429 100,32.712 9.394.099 737331 0333,744 134,646 14,113,139 31,095¢14 107.116 311,012 6,566,949 3,179,472
0.07700 991700 027700 0.07700 007700 007190 0.07700 0.07700 907700 0.07700 0.47709 007700 007700 007700 027700
3,361,211 2.793.914 11.134302 132043 3,633,747 97,640 41,614 369131 7,163 122.470 3431923 13,00 76,763 719,33 743,003
3,391,210 6,217,024 4,112,312 307,039 2,779,470 36.113 19,905 170,761 2,436 396,135 130,990 2.907 13.361 179,10 134.676
1942993 713974 2,733,169 230113 1,332,037 19,331 11,442 92,349 1,736 713,306 633.195 1,263 14,194 10,343 61,227
24,735942 1,331,692 32,393,633 3.415.774 17,109,794 343,661 133,733 1.113,466 31,231 3,313441 9400327 31312 147,104 1}06,404 1362,721
3331437714 11172131% 4731071636 4.11902914 23.7106416 03341323 0.1901304 1.60704914 132139% 3.63619734 17,77270794 0027633% 013334374 16929474 1,33331034
1,653,461,176 753934449 2411.497423 270,622,311 6313.43 11,00930 13,431 453,173 1,974 72.4170 4,046070 1,191,119 9,0*796 34,024.504 14,717363
KWH KWH KWH KWH KW KWH KW !;W KW KW OW KW KW KWH KWH
(1) AT= Wails pepeam. Oat f. I.i Eml 0000.06.
126
Attachment D
Page 4 of 5
000121
Settlement
Allocators
Allocators
Transmission Demand
12CP-TRAN
0.4611205
Production Demand
12CP-PROD
0.519179
Retail Transmission Demand ,
RETAIL-TRAN
0.721246
Transmission Plant in Service
PIS-TRAN
0.4665925
Net Plant in Service
PIS -NET
0.518199
Production, Transmission, Distribution Plant in Service; PIS -PTD
0.523049
General Plant in Service; PIS -GEN
0.579034
Distribution NCP; NCP -DIST
0.9920215
•
Distribution Plant in Service; PIS -DIST
0.64560005
Production Demand; 12CP-PROD
0.519179
Production Plant in Service
0.519179
000121
Attachment D
Page 5 of 5
GOING -FORWARD PENSION AND OPEB BASELINES
As of August 1, 2016, the Texas retail pension and OPEB baselines are $8,796,485 for qualified
pension and $(230,860) for OPEB. Those amounts were calculated as follows:
Those baseline amounts, which are assumed to be included in the Docket No. 45524 Stipulation
revenue requirement of $545 million [Section I(a)], will be compared to the actual amounts that
SPS incurs for pension and OPEB expense beginning August 1, 2016.
CURRENT PENSION AND OPEB TRACKER BALANCE
In the Docket No. 43695 Order on Rehearing, the Commission approved a deferred pension and
OPEB tracker balance of $3,583,510 and authorized SPS to recover that amount over 24 months
starting June 2015.3 That equates to an amortization of $149,313 per month. The rates set in
Docket No. 43695 took effect on June 11, 2015.
Under Section IV(a) of the Docket No. 45524 Stipulation, the amount amortized as of May 31,
2016 is $1,741,985, which is calculated as follows:
$149,313 x 11 months = $1,642,443
$149,313 x .66 = $99,5424
$1,642,443 + $99,542 = $1,741,985
Subtracting the $1,741,985 from the original tracker balance of $3,583,510 leaves a pension and
OPEB tracker balance of $1,841,525 as of May 31, 2016. This is the balance that will be
amortized over a 24 -month period starting July 1, 2016 [Section IV(a)]. The amortization
expense is assumed to be included in the Docket No. 45524 Stipulation revenue requirement of
$545 million. If the entire amount has not been amortized at the time the rates set in SPS's next
base rate go into effect, the Docket No. 45524 Stipulation [Section IV(a)] provides that the
remaining unamortized amount can be included in a subsequent base rate case and is deemed
reasonable and necessary.
i Source: Update Testimony of Richard R. Schrubbe at 7.
2 Source: Rebuttal Testimony of Arthur P. Freitas, Attachment APF -RR -R2 at 43, line 272.
3 Docket No. 43695 Order on Rehearing, Findings of Fact 105-107.
4 The Docket No. 43695 rates were in effect for 20 of the 30 days of June 2015. 20/30 = .66
PUC Docket No. 45524
Unopposed Stipulation, Attachment D
Pension and OPEB Tracker Baseline
Page 1 of 1
000122
127
Calendar Year 2015
Expenses
Jurisdictional
Allocation Factor2
Texas Retail
Amount
Pension
$15,290,257
57.53%
$8,796,485
OPEB
$(401,287)
57.53%
$(230,860)
Those baseline amounts, which are assumed to be included in the Docket No. 45524 Stipulation
revenue requirement of $545 million [Section I(a)], will be compared to the actual amounts that
SPS incurs for pension and OPEB expense beginning August 1, 2016.
CURRENT PENSION AND OPEB TRACKER BALANCE
In the Docket No. 43695 Order on Rehearing, the Commission approved a deferred pension and
OPEB tracker balance of $3,583,510 and authorized SPS to recover that amount over 24 months
starting June 2015.3 That equates to an amortization of $149,313 per month. The rates set in
Docket No. 43695 took effect on June 11, 2015.
Under Section IV(a) of the Docket No. 45524 Stipulation, the amount amortized as of May 31,
2016 is $1,741,985, which is calculated as follows:
$149,313 x 11 months = $1,642,443
$149,313 x .66 = $99,5424
$1,642,443 + $99,542 = $1,741,985
Subtracting the $1,741,985 from the original tracker balance of $3,583,510 leaves a pension and
OPEB tracker balance of $1,841,525 as of May 31, 2016. This is the balance that will be
amortized over a 24 -month period starting July 1, 2016 [Section IV(a)]. The amortization
expense is assumed to be included in the Docket No. 45524 Stipulation revenue requirement of
$545 million. If the entire amount has not been amortized at the time the rates set in SPS's next
base rate go into effect, the Docket No. 45524 Stipulation [Section IV(a)] provides that the
remaining unamortized amount can be included in a subsequent base rate case and is deemed
reasonable and necessary.
i Source: Update Testimony of Richard R. Schrubbe at 7.
2 Source: Rebuttal Testimony of Arthur P. Freitas, Attachment APF -RR -R2 at 43, line 272.
3 Docket No. 43695 Order on Rehearing, Findings of Fact 105-107.
4 The Docket No. 43695 rates were in effect for 20 of the 30 days of June 2015. 20/30 = .66
PUC Docket No. 45524
Unopposed Stipulation, Attachment D
Pension and OPEB Tracker Baseline
Page 1 of 1
000122
127
128
Attachment E
Page 1 of 12
PUC DOCKET NO. 45524
SOAH DOCKET NO. 473-16-2520
APPLICATION OF SOUTHWESTERN § PUBLIC UTIILTY COMMISSION
PUBLIC SERVICE COMPANY FOR §
AUTHORITY TO CHANGE RATES § OF TEXAS
PROPOSED ORDER
This order addresses the application of Southwestern Public Service Company (SPS) for
authority to change rates. An Unopposed Stipulation (Stipulation) resolves all issues in this
proceeding. Consistent with the Stipulation, SPS's application is approved.
The Public Utility Commission of Texas (Commission) adopts the following findings of
fact and conclusions of law:
I. Findings of Fact
Procedural History
1. SPS is an investor-owned electric utility with a retail service area located in Texas.
2. SPS serves retail and wholesale electric customers in Texas and New Mexico. The New
Mexico Public Regulation Commission regulates SPS's New Mexico retail operations.
The Federal Energy Regulatory Commission regulates SPS's wholesale electric
operations.
3. On February 16, 2016, SPS filed an application requesting authority to change its Texas
retail rates. SPS requested an overall increase in base rate revenues for the Texas retail
jurisdiction of $71.9 million per year. SPS also requested approval of a set of proposed
tariff schedules reflecting the increased rates and other revised terms.
4. The test year used in SPS's application was the 12 -month period from October 1, 2014
through September 30, 2015.
5. Under Public Utility Regulatory Act (PURA)t section 36.112, SPS also provided
estimated information regarding increases and decreases in its cost of service for the
period October 1, 2015 through December 31, 2015 (Update Period).
PURA is codified at Tex. Util. Code Ann. §§ 11.011-66.016 (West 2016).
PUC Docket No. 45524
SOAH Docket No. 473-16-2520
- 1 -
Proposed Order
000123
Attachment E
Page 2 of 12
6. Under PURA § 36.211, SPS requested that the rates set in this proceeding be made
effective for consumption on and after July 20, 2016, which was the 155th day after SPS
filed its Rate Filing Package.
7, SPS provided notice by publication for four consecutive weeks before the effective date
of the proposed rate change in newspapers having general circulation in each county of
SPS's Texas service territory. SPS also mailed notice of its proposed rate change to all of
its customers. Additionally, SPS timely served notice of its statement of intent to change
rates on all municipalities retaining original jurisdiction over its rates and services.
S. The following parties were granted intervenor status in this docket: Alliance of Xcel
Municipalities (AXM); Office of Public Utility Counsel (OPUC); Texas Industrial
Energy Consumers; United States Department of Energy; Amarillo College; International
Brotherhood of Electrical Workers Local Union 602; Texas Cotton Ginners' Association;
Pioneer Natural Resources USA, Inc.; Amarillo Recycling Co., Inc.; Wal-Mart Stores
Texas, LLC, and Sam's East, Inc.; Canadian River Municipal Water Authority; Golden
Spread Electric Cooperative, Inc.; and State of Texas Agencies and Institutions of Higher
Education (State Agencies). Commission Staff (Staff) became a party as a matter of
right.
9. All of SPS's timely filed petitions for review of the rate ordinances of the municipalities
exercising original jurisdiction with SPS's service territory were consolidated for
determination in this proceeding.
10. On February 17, 2016, the Commission referred this case to the State Office of
Administrative Hearings (SOAH).
11. On March 17, 2016, the SOAH Administrative Law Judges (ALJs) issued SOAH Order
No. 4, which set the procedural schedule for this docket.
12. On March 25, 2016, the Commission issued its preliminary order, identifying a non -
exhaustive list of 50 issues to be addressed in this proceeding.
13. SPS replaced its estimated information for the Update Period with actual information on
April 1, 2016. On that same day, SPS filed its 45 -day case update as required by the
Commission's Rate Filing Package.
14. SPS agreed to extend the statutory deadline for issuing a final order to January 31, 2017.
PUC Docket No. 45524 Proposed Order
SOAR Docket No. 473-16-2520
- 2-
000124
129
130
Attachment E
Page 3 of 12
15. On August 16, 2016, Intervenors filed direct testimony, and on August 23, 2016,
Commission Staff filed direct testimony.
16. On September 2, 2016, State Agencies withdrew its intervention.
17. SPS filed rebuttal testimony on September 9, 2016. In that testimony, SPS reduced its
requested rate increase to $61.5 million.
18. On September 12, 2016, the ALJs issued SOAH Order No. 7, which severed issues
regarding rate case expenses into Review of Rate Case Expenses Incurred By
Southwestern Public Service Company and Municipalities in Docket No. 45524, Docket
No. 46328.
19. On September 16, 2016, SPS filed an unopposed motion to extend the procedural
schedule by one week to facilitate settlement discussions. The ALJs granted that motion
in SOAH Order No. 8, which was issued on September 19, 2016.
20. On September 26, SPS filed an unopposed motion to abate the procedural schedule to
continue facilitating settlement discussions, and the ALJs granted that motion in SOAH
Order No. 9, issued on September 27, 2016.
21. On December _, 2016, SPS filed the Stipulation, which resolved all issues in this
proceeding. All remaining parties to the case either joined the Stipulation or did not
oppose it. SPS and Staff also presented testimony in support of the stipulation.
22. On December 2016, SPS filed an unopposed motion to authorize interim rates.
23. SPS's interim tariffs are identical to the tariffs agreed to in the Stipulation.
24. On December _, 2016, the ALJs issued SOAH Order No. 10 granting interim rates.
25. On December _, 2016, SPS filed an unopposed motion to admit evidence to support the
Stipulation and to remand the case to the Commission.
26. On December _, 2016, the ALJs issued SOAH Order No. 11 admitting evidence to
support the Stipulation, remanding the case to the Commission, and dismissing the
SOAH docket.
Description of the Stipulation
27. SPS's Texas retail rates will be set to recover a revenue requirement of $545 million, and
SPS's present revenues total $509,750,239, which results in a base rate revenue increase
of $35,249,761 for service rendered on and after July 20, 2016. The increase by class and
PUC Docket No. 45524 Proposed Order
SOAH Docket No. 473-16-2520
- 3-
000125
Attachment E
Page 4 of 12
revenue proof is reflected in Attachment A to the Stipulation. The rate tariffs are
provided in Attachment B to the Stipulation.
28. The proof of revenue provided in Attachment A to the Stipulation reflects $12,599,674 of
revenue attributable to power factor adjustment charges. As described in Attachment C
to the Stipulation, if SPS's actual power factor adjustment charge revenues are less than
$12,599,674 on an annual basis during the applicable period, SPS will record the
difference in a regulatory asset and will be authorized to recover that amount under the
terms set forth in Attachments C and C-1 to the Stipulation.
29. The signatories to the stipulation agreed that:
a. The $35,249,761 rate increase relates back to service rendered on and after July
20, 2016, and therefore SPS may file a motion requesting that the ALJs approve
interim rates for usage on and after the date of the ALJs' order approving those
interim rates. The tariffs authorizing the interim rates will be identical to the
tariffs in Attachment B to the Stipulation. The motion for interim rates will
further specify that the interim rates are subject to adjustment if the interim rates
differ from the final rates the Commission approves in this proceeding.
b. If the Commission's final order in this docket approves the $35,249,761 base rate
increase set forth in the Stipulation, no true -up of interim rates that became
effective under Section II.a. of the Stipulation shall be necessary because the
interim rates will be identical to the final rates approved by the Commission.
c. If the Commission does not approve the Stipulation, SPS shall institute a refund
or surcharge after the date on which the Commission's order in this docket
becomes final to refund the interim rates implemented under Section II.a. of the
Stipulation.
d. For service rendered on and after July 20, 2016 through the day before the date
SPS begins to implement the interim rates, SPS may implement surcharges and
refunds, as applicable, to recover the revenue it would have received during that
period if the tariffs provided in Exhibit B to the Stipulation had been in effect
during that period.
30. The agreed-upon base rate increase does not include rate case expenses, which will be
addressed in Commission Docket No. 46328.
PUC Docket No, 45524 Proposed Order
SOAHDocket No. 473-16-2520
- 4-
000126
131
132
Attachment E
Page 5 of 12
31. The pension and Other Post -Employment Benefit expense tracker balances will be
measured as of May 31, 2016, and the amortization of those balances will begin July 1,
2016. Any remaining unamortized amounts can be included in a subsequent base rate
case filing and are deemed reasonable and necessary.
32. There will be no change in SPS's existing Commission -approved depreciation rates. A
new amortization period of 15 years is established for large base system software assets.
33. The capital additions that SPS closed to plant in service during the period of July 1, 2014
through December 31, 2015 that are included in SPS's Test Year and Update Filing rate
base are reasonable and necessary.
34. The baselines for the Transmission Cost Recovery Factor (TCRF), Distribution Cost
Recovery Factor ("DCRF"), and Purchased Power Capacity Cost Recovery Factor
("PCRF") are attached to this Order as Attachment A. The weighted average cost of
capital for the TCRF, DCRF, and PCRF baselines is 7.7%.
35. The inclusion of separate baseline numbers for the Residential Space Heating rider
customers is not an agreement by the parties that any TCRF, DCRF, or PCRF rate should
or should not be set separately for these customers, or that the separate baseline numbers
for the Residential Space Heating and other residential customers are or are not
appropriate to use in calculating a TCRF, DCRF, or PCRF revenue requirement.
36. All Signatories reserve their rights in TCRF, DCRF, and PCRF proceedings that use the
baselines set forth in Attachment D to the Stipulation regarding whether the TCRF,
DCRF, or PCRF rates should reflect separate rates for Residential Space Heating
customers. In addition, all Signatories agree that any list or any level of detail of the
various ratemaking components (costs, rate base items, jurisdictional allocators, etc.) in
the TCRF, DCRF, and PCRF baselines set forth in Attachment D to the Stipulation are
the product of compromise and settlement, and are non-binding and not to be treated as
precedent in any other proceeding of any kind (base rate, rulemaking, TCRF, DCRF,
PCRF, or otherwise) involving any utility (not just SPS proceedings). Notwithstanding
the agreement in the Stipulation, and except with regard to which of the baseline columns
related to residential customers to use, baseline values set forth in Attachment D to the
Stipulation will be used in TCRF, DCRF, or PCRF cases SPS files before its next base
rate case. SPS agreed to use all columns related to residential customers in those future
PUC Docket No. 45524
SOAR Docket No. 473-16-2520
- 5 -
Proposed Order
000127
Attachment E
Page 6 of 12
TCRF, DCRF, or PCRF applications SPS files before its next base rate case. The fact
that parties have agreed to the use of the baselines as specified in the Stipulation does not
reflect an agreement on any methodology that may or may not have been used to derive
those baselines.
37. For the first TCRF application SPS files after the date the Stipulation is filed with the
Commission:
a. if SPS files a TCRF application that uses test year data only (no post-test year
capital additions, only the level of approved transmission charges incurred during
the test year, with adjustments only to remove non-recurring and out of period
items, and makes a load growth adjustment, parties will not oppose setting a
procedural schedule that includes the following terms: (i) parties will agree to set
a deadline to request a hearing within 45 days of the filing of the application, and
(ii) if no hearing is requested or if the parties reach an agreement regarding all
issues, the parties will make reasonable efforts for a final order to be entered on or
before the 100th day after the filing of the application;
b. SPS agrees to a cap of $19 million (Texas retail) on an annualized basis for the
total amount of the increase that will be implemented;
c. SPS will make a load growth adjustment to reflect actual billing determinants for
the TCRF test year; and
d. SPS will not file a TCRF application before the order entered in Docket No.
45524 becomes a final order under Tex. Govt. Code § 2001.144.
38. Bundled Texas -generated RECs will be priced at $0.39 starting on August 1, 2016. The
Texas Commission will establish the value for Texas -generated bundled RECs and the
New Mexico Public Regulation Commission will establish the value for New Mexico -
generated bundled RECs.
39. The return on equity for Allowance for Funds Used During Construction purposes is
9.6%.
40. For SPS's next base rate case, the signatories agree not to oppose a request by SPS to
waive the requirement to file Schedule S of the current Rate Filing Package, provided
that the test year (or update period) for the next base -rate case ends on the last day of a
fiscal quarter.
PUC Docket No. 45524 Proposed Order
SOAHDocket No. 473-16-2520
- 6-
000128
133
134
Attachment E
Page 7 of 12
41. SPS, Staff, and OPUC further agreed that:
a. SPS, Staff, and OPUC will work cooperatively to develop a Residential Service
(RS) rate design that SPS will propose in its next base rate case that eliminates the
Electric Space Heating Rider (RSH). The new rate design for the Residential
class will be designed to moderate the effect on RSH customers of eliminating the
RSH option, and may include options such as rates that are based on consumption
bands. The new rate design is intended to be revised or eliminated in future rate
proceedings as the need to moderate the effect of the elimination of the RSH
Rider on RSH customers diminishes. SPS agreed to make available upon request
cost and billing determinant information necessary to calculate RS rates based on
initial consumption band alternatives of 400 kilowatt-hours (kWh), 500 kWh, 600
kWh, 700 kWh, 800 kWh, 900 kWh, 1,000 kWh, 1,100 kWh, and 1,200 kWh.
b. If, in addition to the rate design addressed above, further mitigation of rate
impacts for RSH customers is necessary, SPS may propose a temporary rider
designed to provide a credit per kWh to all Residential customers for above-
average residential consumption during the winter months as defined in the
current RS rate tariff (billing months of October through May), to be phased out
over a period of time. The cost of the credit will be recovered through an increase
to the RS energy charge throughout the year, with the increase to be phased out
concurrent with the phase-out of the credit and the phase-out of the RSH rider, in
a manner designed to be revenue -neutral for SPS. The temporary rider will end at
the conclusion of the summer months as defined in the current RS rate tariff
(billing months of June through September) in the third year after the effective
date of the new rates set in SPS next base rate case, unless SPS, Staff, and OPUC
jointly recommend a different ending date and the Commission approves that
date. Rate changes under the temporary rider and the elimination of the rider are
not to occur during the winter months (as defined in the current RS rate tariff).
The target end date for the temporary rider is the end of the summer period
concluding September 30, 2020.
c. SPS, Staff, and OPUC will work cooperatively before SPS files its next base rate
case to: (1) develop a plan to inform RSH customers that the RSH option is
PUC Docket No. 45524
SOAK Docket No. 473-16-2520
- 7 -
Proposed Order
000129
Attachment E
Page 8 of 12
ending and to communicate to RSH customers the value of the Residential Time
of Use Rider; and (2) develop a plan to market the Residential Time of Use Rider
in general. SPS agreed to implement the plans prior to the conclusion of its next
base rate case.
d. Beginning with SPS's next base rate case, any cap on the number of customers
joining the residential time -of -use (TOU) rate plans will not include a limit on
RSH customers seeking to participate in the TOU rate plans.
42. SPS further agreed to conduct a study of cost savings associated with the installation of
LED lighting by municipalities and to present the results of that study in its next base rate
case. SPS agreed that it will confer with AXM as it designs the study, and AXM and SPS
agreed to work cooperatively regarding the study design. By entering into the
Stipulation, no Signatory waived any claim it may have regarding SPS's Tariff Sheet No.
IV -91, Municipal and State Street Lighting Service, or any other tariff for area lighting or
sign lighting.
43. SPS will treat LGST as a single class in its next rate case filing, including for cost
allocation and revenue distribution purposes, SPS will propose a single set of rates for
the LGST class, except that SPS will propose cost -based credit rates for energy and
demand charges applicable to higher voltage customers within the LGST class to reflect
the lower line losses and other identifiable cost differences associated with serving those
higher voltage customers. This provision of the Stipulation is the result of an agreement
between SPS and Commission Staff. The other parties to the Stipulation do not oppose
this provision.
44. For all SPS energy efficiency cost recovery factor ("EECRF") cases filed before the final
order in SPS's next base rate case becomes final, as defined under Tex. Govt. Code §
2001.144, the classes approved in Docket No. 459162 will: (a) continue to be the classes
for purposes of SPS's EECRF cases; and (b) be considered the rate classes in SPS's
"most recent base -rate proceeding" under 16 Tex. Admin. Code § 25.181(c)(49). Those
classes are:
Residential Service;
2 Application of Southwestern Public Service Company to Adjust Its Energy Efficiency Cost Recovery
Factor, Docket No. 45916, Order at Finding of Fact No. 23 (Sept. 23, 2016).
PUC Docket No. 45524 Proposed Order
SOANDocket No. 473-16-2520
- 8-
000130
135
136
Attachment E
Page 9 of 12
Small General Service;
Secondary General Service;
Primary General Service;
Small Municipal and School Service;
Large Municipal Service; and
Large School Service.
45. The signatories to the Stipulation further agreed that:
a. they would agree to request entry of a proposed order;
b. they would jointly request that the ALJ admit certain documents into evidence;
c. they would support the Stipulation before the Commission;
d. there are no third -party beneficiaries of the Stipulation;
e. the Stipulation resolves issues only with respect to the Texas retail jurisdiction
and shall not be binding on or have any effect on proceedings in other
jurisdictions;
f. they are not stipulating to any methodology or theory that may support or underlie
any of the dollar amounts, rates in tariffs, depreciation rates, dollar balances, or
other monetary or numerical values set out in, or attached to, the Stipulation;
g. the Stipulation was drafted by all the signatories and is the result of negotiation,
compromise, settlement, and accommodation;
h. the Stipulation is in the public interest;
i. the terms and conditions of the Stipulation are intended to work in concert with
each other as an integrated whole for the purposes of an outcome in this docket
that is in the public interest and that will result in just and reasonable rates, and
thus the various provisions of the Stipulation are not severable. None of the
provisions of the Stipulation will become fully operative unless the Commission
has entered a final order approving the Stipulation. If the Commission issues a
final order inconsistent with the terms. of the Stipulation, each signatory has the
right to withdraw from the Stipulation, to submit testimony, and to obtain a
hearing and advocate any position it deems appropriate with respect to any issue
in the Stipulation;
j. the Stipulation is binding on each of the signatories only for the purpose of
PUC Docket No. 45524
SOAR Docket No. 473-16-2520
- 9 -
Proposed Order
000131
Attachment E
Page 10 of 12
settling the issues as set forth in the Stipulation in this jurisdiction only and for no
other purposes;
k. except to the extent the Stipulation expressly governs a signatory's rights and
obligations for future periods, the Stipulation shall not be binding or precedential
on a signatory outside of this proceeding or a proceeding to enforce the terms of
the Stipulation;
1. sections I.b., IV.a, VI, VII, IX, XI, XII, XIII, and XIV of the Stipulation all
include forward-looking provisions and corresponding obligations;
m. a signatory's support of the matters contained in the Stipulation may differ from
the position taken or testimony presented by it in other dockets or other
jurisdictions. To the extent that there is a difference, a signatory does not waive
its position in any of those other dockets or jurisdictions. Because it is a
stipulated resolution, no signatory is under any obligation to take the same
positions as set out in the Stipulation in other dockets or jurisdictions, regardless
of whether other dockets present the same or a different set of circumstances,
except as otherwise may be explicitly provided in the Stipulation, Agreement by
the signatories to any provision in the Stipulation will not be used against any
signatory in any future proceeding with respect to different positions that may be
taken by that signatory;
n. the provisions of the Stipulation are intended to relate to only the specific matters
referred to in the Stipulation. By agreeing to the Stipulation, no signatory waives
any claim it may otherwise have with respect to issues not expressly provided for
in the Stipulation;
o. the Stipulation represents a negotiated settlement of all issues in this proceeding;
and
p. each copy of the Stipulation may not bear the signatures of all the signatories, but
will be deemed fully executed if all copies together bear the signatures of all
signatories.
II. Conclusions of Law
1. SPS is a public utility as that term is defined in PURA § 11.004(1) and an electric utility
as that term is defined in PURA § 31.002(6).
PUC Docket No. 45524 Proposed Order
SOAK Docket No. 473-16-2520
-10-
000132
137
138
Attachment E
Page 11 of 12
2. The Commission exercises regulatory authority over SPS and over the subject matter of
this application under PURA §§ 14.001, 32,001, 33.051, 36.001-36.112, and 36.211, and
under 16 Tex. Admin. Code (TAC) § 25.231.
3, SOAH has jurisdiction under this over this proceeding under PURA § 14.053 and Tex.
Gov't Ann. § 2003.049 (West 2016).
4. This docket was processed in accordance with the requirements of PURA, the Texas
Administrative Procedure Act, and Commission rules.
5. SPS provided adequate notice of its application in accordance with PURA § 36.103 and
16 TAC § 22.51.
6. This docket contains no remaining contested issues of fact or law.
7. The Stipulation, taken as a whole, is a just and reasonable resolution of all the issues it
addresses, results in just and reasonable rates, terns, and conditions, is supported by a
preponderance of the credible evidence in the record, is consistent with the relevant
provisions of PURA, and is consistent with the public interest.
III. Ordering Paragraphs
In accordance with these findings of fact and conclusions of law, the Commission issues
the following orders:
1. Consistent with the Stipulation, SPS's application seeking authority to change its rates is
APPROVED.
2. No refunds or surcharges of the interim rates are necessary.
3. SPS is authorized to file applications to implement surcharges and refunds, as applicable,
to recover the revenue it would have received for service rendered on and after July 20,
2016 through the day before the date SPS began implementing the interim rates approved
in this case to recover the revenue it would have received during that period if the tariffs
provided in Exhibit B to the Stipulation had been in effect during that period.
4. Entry of this Order does not indicate the Commission's endorsement or approval of any
principle or methodology that may underlie the Stipulation. Entry of this Order shall not
be regarded as binding holding or precedent as to the appropriateness of any principle or
methodology underlying the Stipulation.
PUC Docket No. 45521
WAN Docket No. 473-16-2520
- 11 -
Proposed Order
000133
Attachment E
Page 12 of 12
5. All other motions, requests for entry of specific findings of fact and conclusions of law,
and any other requests for general or specific relief, if not expressly granted, are denied.
PUC Docket No. 45524 Proposed Order
SOAH Docket No. 47346-2520
-12-
000134
139
140